ML20148R448
| ML20148R448 | |
| Person / Time | |
|---|---|
| Site: | River Bend  |
| Issue date: | 01/29/1988 |
| From: | Callan L NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV) |
| To: | Deddens J GULF STATES UTILITIES CO. |
| References | |
| EA-87-229, NUDOCS 8802020181 | |
| Download: ML20148R448 (28) | |
See also: IR 05000458/1987028
Text
{{#Wiki_filter:jo "%g UNITED ST ATES
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.. NUCLEAR REGULATORY COMMISSION
>'" $ REGION IV
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611 RY A *4 rt AZA DRIVE. SUITE 1000
ARLINGTON, TEX AS 76011
JAN 2 91933
Docket No. 50-458
License No. NPF 47
EA No. 87-229
Gulf States Utilities
ATTH: Mr. James C. Deddens
Senior Vice President, (RBNG)
Nuclear Licensing
P. O. Box 220
St. Francisville, LA 70775
Gentlemen:
This refers to the Enforcement Conference conducted in the NRC Region IV Office
on December 14, 1987, with you and other members of your staff, and Region IV
and Office of Nuclear Reactor Regulation personnel. This conference was
related to the findings of the NRC inspection conducted during the period
November 1-21, 1987, which were documented in our NRC Inspection
Report 50-458/87-28, dated December 7, 1987
The subjects di* cussed at this meeting are described in the enclosed Meeting
Suma ry.
In accordance with Section 2.790 of the NRC's "Rules of Practice," Part 2
Title 10, Code of Federal Regulations, a copy of this letter will be placed in
the NRC's Public Document Room.
Should you have any questions concerning this matter, we will be pleased to
discuss them with you.
Sincerely,
/ pf
G A X CL'
L[.J.Fallan, Director
Divi i n of Reactor Projects
! ! Enclosure:
Meeting Summary
I
cc w/ encl: (see next page)
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JM 2 91983
Gulf States Utilities -2-
cc w/ enclosure:
Gulf States Utilities
ATTN: J. E. Booker, Manager-
River Bend Oversight
P. O. Box 2951
Beaumont, Texas 77704
Louisiana State University,
Government Documents Department
Louisiana Radiation Control Program Director
'bec to DMB (IE45)
bec distrib. by RIV:
DRP Resident Inspector
R. D. Martin, RA Section Chief (DRP/C)
Lisa Shea, RM/ALF RIV File
RPSB-DRSS
Project Engineer, DRP/C
W. Paulson, NRR Project Manager
DRS
D. Powers
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Eholler:vsa DAPowers LJCallan RCMartin
1/ 1/88 1/L9/88 1/ /88
1/Gf/88
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ATTACHMENT
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GULF STATES UTILITIES
'
DECEMBER 14, 1987
l !
MEETING SUMMARY
,
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Licensee: Gulf States Utilities (GSU)
Facility: River Bend Station (RBS)
.
License No.: NPF-47
Docket No.: 50-458 ,
SUBJECT: ENFORCEMENT CONFERENCE CONCERNING NRC INSPECTION FINDINGS
(INSPECTION REPORT 50-458/87-28)
On December 14, 1987, representatives of Gulf States Utilities, met in
Arlington, Texas, with NRC Region IV and NRR personnel to discuss the findings
documented in the NRC Inspection Report dated December 7, 1987. The attendance
list and licensee presentation are attached. The meeting was held at the
request of NRC, Region IV.
The NRC discussed its concern regarding a mispositioned process isolation root '
valve for one channel of high drywell pressure instrumentation. The licensee
discussed the cause for the mispositioned valve, how the problem was !
discovered, the safety significante of the matter, and corrective actions taken ,
by the licensee. }
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Enclosures:
1. Attendance List
2. GSU Presentation
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j ENCLOSURE 1 l
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ENFORCEMENT CONFERENCE ATTENDANCE LIST - REGION IV i
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GULF STATES UTILITIES .
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I NRC Attendees: J. Montgomery, Deputy Regional Administrator
- J. Callan, Director, Division of Reactor Projects
A. Beach, Deputy Director, Division of Reactor Projects : J. Milhoan, Director, Division of Reactor Safety
D. Powers, Enforcement Officer ! J. Jaudon, Chief, Projects Section A ! D. Hunter, Chief, Technical Support Section
'
W. Seidle, Chief, Operational Programs Section
l G. Madsen, Acting Chief, Projects Section C !
- D. Chamberlain, Senior Resident inspector ;
, W. Paulson, Project Manager, NRR ' ,
H. Scott, Enforcement Staff
i i
Licensee Attendees: J. C. Deddens, Senior Vice President, River Bend
.
Nuclear Group
l J. E. Booker, Manager Oversight
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E. R. Grant, Director, Nuclear Licensing
T. F. Plunkett, Plant Manager
- M. Sankovich, Manager Engineering .
I D. Williamson, EPS Supervisor j l J. Schippert, OPS ENG i i
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not.a Utu 131987 lywt
Deceber 14, 1987
RIVER Ba'D
Page
HERDIXITIQ1 u,
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SDKU4CE OF EVDES 2,3,4
SYS'1Hi 1DGIC 5,6,7,8,9
SAITIY SIGEFICMiCE 10, 11, 12, 13, 14
CDRRECTIVE 4CTIQi 15, 16
SlWARY 17, 18
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INIFODUCTION
August 29, 1985: River Bend receives its Irv Power License October 31, 1985: River Bend enters !bde 2 and reaches initial
criticality
tbvenber 20, 1985: RBS receives Full Pcuer License Decmber 3, 1985: Initial Generator Synchronization Septmber 14, 1987: RBS shut dcm for first re.#ueling outas;e Novecber 17, 1987: Poutine refueling outage Limtps on thiclear Boiler l
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Instn:vntation (SOP-001) were being perfonvd when
operators identified the as found condition of
1RCS*V122 closed. They immediately identified this
condition to their supervisors, the !RC, and the
Plant !bnager, and initiated a Condition Peport,
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SEQUENCE OF EVENTS
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SEQLTNCE OF EVDirS
July 5, 1985: S'R 04128 written on valve RCS*V122 identifying
missing valve packing bolts.
August 13, 1985: SOP-001 (Nuclear Boiler Instnrentation) valve
lineup perforned. RCSM'122 not signed off - noted
need to repair.
!UIE
he lineup had been revised via Tmporary Change !;otice imi)
to renwe every other itctn (they were being transferred to a
separate I&C attachment).
August 15, 1985: Shift Supen*isor reviewed the lineup for
ecnpletien, overicoki'u the failure to ccrplete
RCSME 2,
August 29, 1985- PSS re eives 1cu pcuer license. Unit enters Mode 5
the fv11cving day. I.6stnrvnts from RCS%r122 !Ur
required cperable.
Septaber 6, 1985: !KR 04128 released for wrk -
No "Tracking IID"
written.
!UIE
We "Tracking 100" syst.czn was written into procedures 8/31/85.
Review and approval received 9/10/85. Distribution to muual
holders was made 9/12/85.
j October 25, 1985 SR 04128 signed off cocplete. !b work ) instnictices to check writion of valve. 1 October 31, 1985 Unit enters Pode 2. Instnrents off of RCS%'122 ] required operable for first tire.
!UTE
We Dryw11 Press instn:vnts are unique in that the process
ptuvides a : ero reading "at all tires - as would an isolated
instnrent. Werefore, channel checks" throudrut the cycle
.! w uld not identify this condition as they would for other
instnrents.
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' l VALVE t.!NEUP - NUCLEAR BOILER CATE: 613 F3 I
ATTACHMENT - 1
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INSTRUM:NTAT 0N l
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(SAFETY RE!ATED)
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yALH VALVE NAME REQ'O
I INITIAL 5 * Aq1 gat
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NUMBER (OR DESCR!."7 TON)
Upstream Root
POSIT 10Nl1st!2nd I
POSITION '
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1RCS-V84 Low Side Root for the Folicwing qf ' '
Instruments OPEN
! 1821 t.T-N095A . IC33.Li-N004A ; ' 4g
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IB21 LT-N080A
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1RCS V85 ~~c d
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Downstream Root OPEN
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pr.ir.
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Same description as IRCS V84
Upstream Root
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1RCS-V80 Hi Side Root for the Follcwing
4
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Instruments
1821-LT h080C 1821-LT-N081C
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1C33-LT-N004C
1821-LT-N044C
1821 LT-N073C OPEN (,%,
.. CfW
I 1821-LT-N073G
I Se, aC, Root for the following instrument
1821-PT-N078C
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1RCS-v81 Downstream Root Teel
! Same description as IRCS-V80
OPEN 85 ift
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Upstream Root
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1RCS V82 Low Side Root for the Following I
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Ins truments
IB21-LT N080C
OPEN <h M4h[jcPOJ
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IC33-LT N004C v
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j 1RCS-V83 Downstream Root CFEN
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5
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Same description as 1RCS V82 ,
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Upstream Root '
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; 1RCl-yj6 _ I'I Lew Side Root for the Follcwing j
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Instruments l' OPEN I
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j 1821 LT N081C 1821-LT-N073G
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1RC5.V87 ' I I Ip.
! I'DownstreamRoot
Same description as 1RCS-V86 I
OPEN Br 4 8.
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I 'i:C5.V122 I j j j j r
j ! lRectfortheFollcwingInstruments
1821-PT-N067G 1C71-PT-h050C
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l1RCS-V123 ~ 1821 PT-N094A !'l
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1C71 PT N050A
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CFEN
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IB33 PT N05CA l l
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! isCS-V120 Root for the Folicwing Instruments l I..! I I
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1521-PT-NC948 1C71 PT N0508 : OFEN
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a21-,T.NC,u n n -PT N050B ; ; ;7%hd, usa./l ,
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VALVE LINEUP NUCLEAR 80!Lt.R OATE: 8 # bW I
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aiiackMENT - 1 INSTAUMENTATION
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(SAFETY RELATED)
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I-~~ 7A v g vat.yg NMg INIFIAL5 ACTUAL
I m '.tC E R (OR DESCR!PTION) P05tTION 1st ' 2nd POSITION
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; Upstream Root if -
: i t.5.V118 Low Side Root for the Following '
l Instr ,
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1833FT.N0378
' aments 1833.FT.N037M
.Q O
l 1833.FT.N0370 1833 FT.M037P OPEN L
chd
i 1833.FT.NO37F 1F33.FT.N0375 D '
i 1833 FT.N037H 1833.FT.N037U
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1833 FT.NO37K 1833.FT.N037W
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*103.V124
. Downstream Root CPEM gr. ig:
Same description as 1RCS.V118
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U ' .Y20 Upstream Orain Yalve Above Core CLOSED o n s,c
5-. ..
Plate Pressure Instrument Line
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Onwnstream Drain Valve Above Core CLOSED M -Is. '
!..itcs.V2 --
Plate Pressure Instrument lire
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DRYW:LL ~3RESSUR B TRANSk:IT"ERS
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INSTRUMEtJTATIOtJ--- CONTAltJMEtJT O !!JSTRUMEllTATIOt1 LO
ROOT VALVE (IYP) < m
RPS HPCS HPCS HPCS HPCS RPS
PT 7-- - _-
R
Rx
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X X X VESSEL X X X
v119 l ~
V122
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LPCI B LPCI B DRY LPCS LPCS
LPCl C LPCI C V! ELL LPCI A LPCI A
RPS ADS B ADS B ADS A ADS A RPS
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v120 v123 N E X
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:llPS SCLRAN mOG':C -
D RYW i::mL PR ESS~U.LRE
LOST 'i/4 OF THE LOCiC !!Jr'UT
RPS
PT
A
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\ -
RPS
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PI3
ITJIII A TE
AND SCRAM
RPS
PT
g RPS SCRAM SIGNAIS
g g DRWE! L PRESSURE HI
i T RF ACTOR 1 EVEL LOW
OR ~
RiACIOR LEVEL HI
RPS
j ) REACTOR PRESSURE HI
TiiERMAL FLUX HI
APRM FLUX HI
CP5'N
D ,/ 1RM Fl UX HI
SRM FLUX HI
STE AMLINE RADIATION H!
STE AutiNE ISOLA TlOfJ VALVES Cl OSED
<
TURBINE STOP VisLVES CLOSED
! TURBiUL CONTROL VALVES CLOSED
SCRAM DISCHARGE VOLUME LEVEL HI
! MANUAI
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-_ . _ - - - _ - .--
3CS IX T AT ON m0GIC -
DRYWE;m P:R BSSU R B -
HPCS LOST 1/2 OF TtiE LOGIC INPUT
@
3 3
OR -
tiPCS
@
h AND
'^
tiPCS tiPCS
,
HPCS INITIATION SIGNAIS
T ORYWELL PRESSURE fil
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REACIOR LEVEL LOW
OR ^
MANUAL
liPCS
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CON"AIXYEN" ISOLAT:0X / DIVIS 0NAL INIT:AT:0N
LOGIC -
DRYWEL1 PRESSUR3 HI
LOST 1/2 OF THE LOGIC -
RPS
CONTAINMENT ISOLATION
27 VALVES AND DAMPERS AFFECTED
OPT
A
ISOLATE
NOTE: MSIV RCIC, RWCU, RHR-SDC
OUTBOARD
ISOLATIONS ALWAYS REMAIN FULLY
AND FUNCTIONAL.
RPS INITIATE DIVISIONAL INITIATION
, DIV 1 T STANDBY GAS TREATMENT
ANNULUS MIXING
FUEL BUILDING EXHAUST FILTRATION
pps CONTAINMENT HYDROGEN ANALYZER
LOAD SHED
SYSTEM VALVES
B
ISOLATE
INBOARD
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AND ~
ISOLATION / INITIATION SIGNALS
RPS IN TIATE
DRYWELL PRESSURE HI
REACTOR LEVEL LOW
MANUAL
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--_ _ _ _ - - - _-_ - _ _- _ _. - .. ..
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TYPICAL ISOLATEON VALVES AND DAMPERS
LOST DRYWELL PRESSURE HI AUTO ISOLATION
CONTAINMENT b
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, SECONDARY
b-
AUXILIARY CONTAINMENT
PURGE BUILDING ISOLATION
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2 1 2 1.P P PVLCS
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PROCESS
1
LINE (IYP)
~~ ~~ ~~
!
DIVISION 2 ISOLATION LOST:
j 8 DRYWELL ISOLATION VALVES
: 11 CONTA!NMENT ISOLATION VALVES
i 6 SECONDARY CONTAINMENT ISOLATION DAMPERS
j 2 PVLCS VALVES
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SAITIY SINITIGNCE ANALYSIS '
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High Drywell Pressure Autcmatic !
Safety Functicus Not Available with ;
Process Fat Valve PCS*V122 Shut ;
!
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Function Duration Cause
Reactor Scram 45 min /conth Required Testing HPCS Initiation 90 min /conth Bequired Testing
i
Group of Contaiment 90 min /conth Required Testing ! Isolation Valves j
t
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STBY Gas Treat Initiation (*) 2 days 22 hrs (.4 Div 1 Train Incp !
90 min /conth Required Testing l
!
Amulus Mixing Initiation (*) 10 hrsN Div 1 Train Inop
90 edn/ month Required Testing
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Fuel Bldg. Exh. Filt.(*) 10 days 18 hrs (') Div 1 Train Inap
Initiation 90 min /conth Required Testing ,
H2 Analyzers Initiation 5 days 5 hrs Div 1 Train Incp l
90 min /conth Required Testirg
Group of Ioad Shed Breakers 90 min /nonth Required Testing (*) The Division I isolation of the normal ventilation cm High Drwell
Pressure would have still initiated Division II of these systans even
den Division I was inoperable.
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SAFEIY SIGNAIE/SY5' IDS AVAIIABLE
- RPS actuation (scram) cm Dryw11 Pressure High was available via "A" and
"B or D" chamels.
- HPCS initiation on Dave 11 Pressure High was available via "R and L"
chamels.
- Contaiment isolation on Drywell Press Fich was available via "A and D"
channels to outboard isolation valves.
!UTE
MSIV RCIC steam supply, LEU, and RHR-SDC isolations remained
fully functional.
- Division I ventilation rmained available fuc auto start on Dnwil ~
Pressure High via "A and D" isolation logics.
- Division II SBGT, Amulus Mixing, and Fuel Be'1 ding Exhaust Filtration
wuld have received an auto start on nomal ventilation icv ficv frm its Division I isolation on High Drwell Pressure.
- During loss of Offsite Pcver event, all initiatims, isolations, and lead
sheds (prior to D/G tie to the bus) will occur m both divisicus due to failed safe logic.
- At all tires cultiple redundant indication of actual Dow11 Pressure
existed.
- '1% separate independent amunciators on Dnvell Pressure High (belcv the
1.68 psi trip) were available at all tires.
- 14 annunciators signaling one of four (typically - sm e vere one out of
tm) Dnwil Pressure High instnrvnts tripped (at > 1.68 psi) were
available at all tirus.
-11-
OWm0L R0ct4 MRE; CIA 10RS
Alam Panel Windcv Title Setpoint
P601 16-B05 HPCS Initiation D:'sull Pressure
,
1.68 psid
High
P601 17-E01 1.PCI & Div I! D/G Initiation High
IM Preemre 1.68 psid
P601 17-E03 ITCI & Div II D/G Initiation Auto
or !Snual 1.68 psid
P601 19-A09 Div II ADS logie High Dasv11
Press Scaled In 1.68 psid
P601 19-B02 Div I ADS logic High Dr sell
Press Scaled In 1.68 psid
t
P601 20-E06 Div I MR Systm Actuated 1,68 psid
P601 21-B08 LPCS Syst m Activated 1.68 psid
P601 21-E07 Div I ITCS Init D:'.sv11
'
Pressure High 1.68 psid .
!
P680 04-B01 HPU A IV High Press Interlock 1.68 psid
P380 04-B07 HPU B IM High Press Interinch 1.68 psid ;
P680 05-B02 Desv11 High/Im Pressure + 1,2,
- 0.3 psid L
P680 06-E02 !!SSSS Init Dt,wil High Pressure 1,68 psid
P808 83-G04 CIPr/Dt'wll Diff Press High/Im + 1.08, 4
- 0.18 psid l
P808 84-004 Cair/Dnwil Diff Press High/Im * 1.08, !
- 0.18 psid l
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QWGOL RtXH INDICNIURS I
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P808 OG-PP2A -
l Q S-PP2B
P819 OS*ESX29A
J
P842 OS*EST.29B
!
P625 B21*N667G ) PfS*V122
] B21*t:667C ) isolated
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P618 B21ft 694B
! B2Dt;694F ) P629 B21*N694A
- B211N694E
P693 C71M;650C ) RCS*V122
isolated
j P691 C71*S650A
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P692 C71*t:65CB
i l P694 C7111:650D
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COFSICnVE ACn0t3
HARDWAFI FIIATED
- Valve IRCS*V122 correctly positioned epen.
- 100% of all Safety Polated systm valve lity.ups (a total of 11,708 safety
related valves) are being perfonmd prier to start-up. This includes an independent verificatien of preper valve position.
- All M,0 job plus for work en any valve require positiening prior to
ccepletien.
- All process root valves supplying instn:mnts which nomally read aero
vill ncv be sealed open and verified open at each refueling cutage.
- All fcur Dryw11 Pressure instnnmt penetratiens and instnnmt tubirs,
wre verified open and free of obstniction during the Dnwil Bypass
Test.
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COPRECTIVE ACTICt?S
ADENIS"GATIVE O2TEOL
- The "Tracking 140" systm was inp1(wnted to ensure this t'ge of kncun
probim is not overlooked.
,
* Initially inpimented in Sept (rter,1985.
* Has worked very effectively since then.
- Operations perfotrs lineup verification en ECCS and DG systms wekly, as ,
epposed to the Tech Spec required renthly frequency. QA is continuing to
randmly audit these system lineups.
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- khen rajor work is perforced on systms, cceplete lineups are donc prior l
to return to service . Each cycle,100% of all saferv related systms' lineups are performd.
- Additional Operations ranagctrnt reviw of ecvpleted valve lineups
. ired to assure adequacy of problem disysition. Also serves as i endent check on cctpletion.
- QA is auditing 100% or the ccepicted cafety related systes' lineup
sheets. .
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S11tuRY
* Foot cause of occurrence is personnel overs.pht.
* Contributing cause was inadequate Klintenance wort job plan.
* nis event is distinctly different frce other "mispositioned valve"
events previcualy reported:
* Operations personnel involved, not ISC. '
* In previous events, &>ctrentation indicated the valve was independently
verified open. Corrective action addressed inadequate indepedent
i verification practices. In this event, doctrentation was inemplete
; and did not support the valve being epen. Corrective action adds an
independent revis of doctrentation for empletion.
* B e safety significance of this event was
4
- * loss of a group of isolaticus on High Dnsvil Pressure for brief
j periods of surveillance testing
) ' loss of scram signal en High Dow11 Pressure for brief priods of
'
su:veillance testing
* loss of HPCS initiation en High Dnw11 Pressure for brief periods of i
su:ve111ance testirg ,
'
* loss of Divisim II Contaitrent Hydrogen ronitor initiation en High
) Daw 11 Pressure
* Ioss of Divisicu II load shed of non-safety related loads ,
' h is was mitigated by:
* All outboard isolaticus were operable.
* All MSIV, FKU, RCIC stean supply, and FNsbutdcsn ecoling isolations ;
vere operable. <
l ' Several other autcratic signals existed for these systms. l'
l * Manual initiaticn/ isolation capability was available.
- * thitiple, diverse indication and alam ftmetions en Dnvell Pressure '
vere available.
* Operator action is clearly required by ARP, AOP, E0P, to initiate
- appropriate actiens in the event of High Dryw11 Pressure event.
1 * Corrective acticns included: )
* Additicnal reviws of ccepleted lineups (including OA audits)
i
l * Scaling all process root valves to norcully zero reading instnrents
'
* Irp1mentatico of a "Tracking ID7' systm
i l * Ccmwisticn of cperators involved in identifying the probim will ensure
no negative feedback which cculd prmrte a less than emplete acccunting
j of these types of events. It is our goal to raintain the highest level
- of professicnalism. To attain this, cceplete inhindered access to and
j solution of even the scullest of prob 1ms is a rust. '
* To further this goal, River Pend Operaticus is develepirg a I
Professicnal Code of Cenduct.
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MEMORANDUM
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< , l T0: Gr.o Push Scw rber 19, 1987 '
Dave Iccrey
) I?Cfi D. W. Willi cscn J j SLW: Cctrendaticn for Professicnal Attitudes a
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Curing the perfen ance of the systcra liro up fer SCP-0001 ycu disc 7/ered cles(d I
the pmmss rcct valvo fer eno channel of Crf. ell High Pressure
'
instruvntatien. Uren disccver/ ycu ccrrectly repcsitiened the valve,
imodistely notificd ycur supervisicn and initiatcd a Ccnditicn Fcycrt.
Se disccvery of this risicsiticr.ed valve eculd Pave easily rcra ir.ed
j "urdisce/ercd" by repositiening and not rescrting it. Mcw ver, the actiens you a trek are wrthy of crrrendation in that ttey enrplify the professieralim, '
integrity and attentien to detail rccessar/ to bring the quality of cperations ,
at River Bend to the highest stardards. ;
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