ML20129H893
Text
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Voif Electric Generating Plant
"** b 06-C NUCL 44 OPERATIONS j
(
o COMMON Geogia h e
ag. g y afas/sg unit x--------
UNIT NO.
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1 UNIT COOLDOWN TO COLD SHUTDOWN j
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j 1.0 PURPOSE This procedure provides instructions for maintaining hot standb following reactor trip, maintaining hot I
standby fo lowing reactor shutdown, taking the unit from hot standby to cold shutdown.
Instructions are i
provided for maintaining conditions stable at points between.
2.0 PRECAUTIONS AND LIMITATIONS l
2.1 PRECAUTIONS J
2.1.1 If this procedure is terminated prior to completion, the Unit Shift Supervisor (USS) should note the reason for the termination in the comments section.
l 2.1.2 The Reactor Coolant System (RCS) pressure and temperature shall be maintained within the operating region of Figure 1.
2.1.3 Do not add positive reactivity by more than one l
controlled method at a time while the reactor is suberitical.
f l
Whenever RCS temperature is above 160*F, at least one 2.1.4 i
RC,P should be in operation.
Preferably Pump 4 to ensure best' spray capability.
i h to less tken concentration in the RCS mus The hydro 2.1.5 an 5cc/kg prior to opening any RCS component, i
j or use Op s sweb.e e c,,d i-2C ~V Fce pas' er * r~ic 2.1.6 The boron concentration in the pressurizer should not j
be different from the RCS by more than 50 ppa.
Pressuriser Backup Heaters may be energized as necessary to equalize the boron, concentration.
t 2.1.7 The Control Rod Drive Mechanism (CRMO Cooling System shall be operating when RCS t erature is greater than or equal to 350*F or when any is energized.
RECORD COPY
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2.1.8 During cooldown, all Main Steam Isolation Valves (MSIVs) should be open or atmospheric reliefs balanced to allow uniform cooldown of all Reactor Coolant System (RCS) loops and Steam Generators (SGs).
Steam dump is i
i
- the preferred method of heat removal.
l 2.1.9 The Residual Heat Removal (RHR) Pump Suction Line i
should not be isolated from-the RCS unless there is a steam bubble in the Pressurizer.
)
2.1.10-One Reactor Coolant Pump (RCP) should be running anytime RCS temperature is changed by more than 10*F in one hour.
2.1.11 Spray flow into the Pressurizer should not be initiated i
if the temperature difference between the Pressurizer steam space and the spray fluid exceeds 125'F. -
2.1.12-Before auxiliary spray is initiated with a temperature j
difference between the pressuriser steam space and the i
spray fluid exceeding 320'F, notify the USS.
l (Technical Specification 5.7.1) 2.1.13 While in Hot Standby, feeding Steam Generators should be continuous to minimize thermal stresses on the Feedwater Nossle.
2.1.14 Vacuum should be maintained on the Main Turbine j
following unit shutdown until the Turbine coasts down to approximately 66% rated speed (1200 rpm) unless an j
emergency dictates rapid coastdown of the Turbine Rotor.
l 2.1.15 The Main Turbine should be kept on Turning Gear until i
metal casing temperatures have returned to ambient.
l Bearing lube oil circulation must also be maintained.
[
2.1.16 During periods of operation with the RCS level below the Reactor Vessel Flange elevation (194 feet elevation), ongoing work activities should be closely scrutinized and any work activity limited that has the potential for reducing RCS inventory.
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2.2 LIMITATIONS i
2.2.1 The RCS pressure and temperature shall not exceed 425 i
psig and 350*F when open to the RHR system.
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2.2.2
'While in Modes 3 and 4, shutdown margin shall be
)
greater than or equal to the limit specified in Technical Specification 3.1.1.2, Figure 3.1-1.
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2.2.3 While in Mode 5, shutdown margin shall be greater than or equal to the limit s weified in Technical l
Specification 3.1.1.2, figure 3.1-2.
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1 2.2.4 While in Mode 3, at least two RCS loops shall be in operation with the Reactor Trip Breakers closed and at l
least one in operation with the Reactor Trip Breakers (Technical Specifications 3.4.1.2)
I open.
j 2.2.5 While in Mode 4, at least two RCS loops and/or RHR trains shall be operable and at least one of the RCS l
loops and/or RNR trains shall be in operation.
(Technical Specificaeions 3.4.1.3) j f
I 2.2.6 While in Mode 5 with the RCS loops filled, at lesst one f
RHR train shall be operable and in operation and either one additional RHR train operable or the secondary side water level of at least two steam generators shall be i
j greater than 17% wide range.
(Technical Specification 3.4.1.4.1)
I 2.2.7 While in Mode 5 with the RCS loops not filled, at least two RHR trains shall be operable and at least one RHR train shall be in operation.
(Technical Specification 3.4.1.4.2) l l
2.2.8 While in Modes 4, 5, and 6 with the Reactor Vessel Head on, at least one of the following cold overpressure l
protection systsas shall be operabler Two PORVs with lift settings which do not exceed l
the limits established in Figure 1, a.
b'.
Two RER suction Relief Valves each with a setpoint of 450 psig *32, or The RCS depressurized with an RCS vent capable of c.
relieving at least 670 spa water flow at 470 psig.
(Technical Specification 3.4.9.3) l While in Modes 5 and 6, at least one Charging Pump in 2.2.9 the required boron injection flow path shall be operable.
(Technical Specification 3.1.2.3) i 7e064 -
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VECF 12006-g 10 4 of 42 J
i The primary to secondary pressure differential shall 2.2.10 not exceed 1600 paid or a secondary to primary pressure differential of 670 paid during unit operations or leak j
tests.
O.2.11 The maximum cooldown of the RCS shall be limited to
~
100*F in any one hour period.
(Technical Specification 3.4.9.1) ressurizer shall be i
2.2.12 The maximum cooldown of tha ILuited to 200*F in any one our period.
(Technical Specification 3.4.9.2) i The maximum temperature differential between auxiliary 2.2.13 spray water and pressurizer steam space is 625'F.
j (Techical Specification 3.4.9.2) i The temperature of both the primary and secondary l
2.2.14 coolant in the Steam Cenerators shall be greater than 70*F when the pressute of either coolant in the Steam Generator is greater than 200 psig.
(Technical i
Specification 3.7.2)
While in Modes 3, 4 and 5, both channels of Source i
2.2.15 Range Nuclear Instrumentation shall be operable.
i (Technical Specifications Table 3.3-1, 6.B)
~While in Modes 3, 4, and 5 at least one channel Source i
2.2.16 Range Nuclear Instrumentation should be selected to i
Recorder NR-45 and the CONTROL ROOM HI FLUX LEVEL AT SHUTDOWN alarm operable.
I While in Modes 5 and 6, with the RCS level below I
2.2.17 Reactor Vessel Flange elevation (194 feet elevation),
the RWST will be operable with a mininam volume of I
70,832 gallons (51 of instrument span) of water at a l
bo'ron concentration between 2000 and 2200 ppe.
3.0 INITIAL CONDITIONS l
The reactor is shut down either follovig normal l
3.1.
shutdown or reactor trip with Shutdown Rods either i
withdrawn or inserted.
RCS temperature is stabilized at no load Tavg under l
3.2 control of the steam dumps in Steam Pressure mode or' by operation of the Steam Generator Atmospheric Relief l
Valves.
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3.3 RCS pressure is stable at normal operating pressure.
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Pnoctouma No.
kevision VEGP 12006.
10 5 of 42 j.
f 3.4 JLt least one RCP is operating.
I Pressurizer level is at ap3roximately or returning to 4
3.5 the program level with eit3er the Positive Displacement Pump or a Centrifugal Charging Pump (CCP) i
.(PD) operating to supply normal charging and RCP seal i
injection flow.
l SG levels are at 45% to 55% NR level with Auxiliary 3.6 Feedwater (AFW) operating.
The main Turbine is tripped and either coasting down or 3.7 3
on the Turning Gear.
j 4.0 INSTRUCTIONS NOTES This procedure is divided a.
into sections which permit either cooldown or maintaining
,j' stable conditions within a specified mode.
Section E may be performed concurrently i
with Sections A,B,C D.
b.
Asterisk (*) steps beside i
INITIAL steps indicates steps that generate additional i
documents.
2 This procedure is written using l
Train A designations.
Train B c.
component designations are l
shown in parenthesis.
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The sections of this procedure are:
i I
A.
Hot Standby Following Reactor Shutdown or Trip.
i B.
Cooldown to not less than 350*F.
C.
Cooldown to not less than 205'F.
i D.
Cooldown to Cold Shutdown (less than 200*F).
E.
Secondary Plant Shutdown, i
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FAGE No.
MtoC40UftE No.
AgypsH)N VEGP 12006 10
$ of 42 i
!e SECTION A:
Hot Standby Following Reactor Shutdown or Trip A4.1 OPERATING IN HOT STANDBY FOLLOWING REACTOR SHUTDOWN OR TRIPr INITIALS i
i A4.1.1 If this procedure has been entered from a reactor trip, then perform the following:
i INITIATE 10006-C, " Reactor Trip 6
i a.
L Review",
i b.
If entering this procedure from SI termination, then perform 1-11886, " Recovery From ESF l'
Actuation",
If required, INITIATE STARTUP c.
of the Auxiliary Boiler per 13760-C, " Auxiliary Steam Boiler p,
j 1
System",
NOTIFY Chemistry Department, d.
If applicable, ENSURE that TDAFV Pump has been stopped per 13610, 1
" Auxiliary Feedwater System" and returned to STANDBY per 13610, M4*
Checklist 2, i'
(
i BYPASS the ATWAS Mitigation f
e.
System Actuation Circuitry (AMSAC) by performing the following:
(1) nt the AMSAC' Cabinet, PIACE the System Bypass Switch to the BYPASS
/p
- position, (2)
At the AMSAC Cabinet, f
VERIFY the Channel / System Bypass Light illuminates, (3)
VERIFY Annunciator AMS'AC
/
TROUBLE (ALB 05 E04) illuminated.
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Aswsion I.ca no.
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VEGF 12006-10 7 of 42 I
INITIALS I
f.
When Source Range channels
' indication stabilize PLACE CONTROL ROOM HI FLUX LEVEL AT SHUTDOWN alarm in operation by performing the following:
4 (1)
NOTIFY IEC and RESET the HI FLUX AT SHUTDOWN alarm
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sethointper24695and 246 6, "N.I. System Source
(
i Range Channel Calibration",
(2)
ENABLE THE HI FLUX AT SHUTDOWN f
alarm b lacing the HIGH FLUX
(
AT S d NORMAL / BLOCK j
switches to the NORMAL,
/.
(3)
VERIFY annunciator SOURCE RNG HI SHUTDOWN FLUX ALARM BLOCKED ALB-10 B01 resets, i
I (4)
SELECT both channels of Source indication on Recorder
{
t ANNOTATE chart to reflect
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channels selected, T
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3 CALCULATE SHUTDOWN MARGIN per 14005, " Shutdown Margin
{'
Calculations",
h.
If necessary, BORATE the RCS per 13009, "CVCS Reactor Makeup y*4 Control System",
1.
SHUT DOWN the CVCS BTRS System by i
performing the following:
'(1)
FLACE the CVCS BTRS SELECTOR i
Switch HS-10351 in the OFF Ag
- position, I
L (2)
CLOSE the BTRS Domineralizer Flow Control MV-0387.to the N,
FULLY CLOSED position,
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[MeoCEDURE No.
s,EvtSION eAGE No.
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VEGP 12006-4 10 8 of 42 INITIALS I
i J.
DIRECT Chemistry to sample the RCS hydrogen, gas activity concentrations and PERFORM an RCS l
Iodine sample analysis per the i
required frequencies of Technical Specifications Table 4.4-4,
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Time / N.3 Person Contacted i
k.
MAXIMIZE CVCS letdown purification flow rate per 13006, " Chemical And Volume Control Sgstem Startup
(
i And Normal Operation NS8/ /7f.3
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Date Time I
1.
MONITUR Main Turbine coastdown, l
(1)
ENSURE that the Turning Gear Motor Control Handswitch is in AUT0/ PULL-TO-LOCK position, (2)
When Turbine Rotor reaches zero l
speed, VERIFY all Lift Pumps, i
l Turning Gear Oil Pumps ON and i
Turning Gear engagement.
b m.
STOP both Heater Drain Pumps, b
n.
STOP all but one Condensate Pump, 1
L o.
REDUCE in-service Condensate Domineralizer Powdex Vessels as l
applicable per 13616, " Condensate Filter Domineralizer System",
4 p.
PLACE the Condensate and Feedwater System on Long cycle recire per 13615, " Condensate And Feedwater
(
Systems",
q.
NOTIFY Chemistry to initiate placing condensate and feedwater into proper chemical wet layup, r.
If necessary, SHUT DOWN all but one Circulating Water Pump, v
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'PMoCEDUAE No.
AsylS12N PAGE NO.
VEGP 12006 10 9 of 42 l
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INITIALS i
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If necessary, SHUT DOWN all but one s.
River Makeup Pump and RECORD time
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in the Unit Control Log Book, i
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t.
ENSURE SG Blowdown Isolation Valves
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l-HV-7603A(B, C, D) open.
A4.1.2 If No-Load Tavg cannot be maintained due to excessive steam demand, REDUCE steam demand by performing the following:
ValvesRS-6015angRS-6030 ply
(
l ENSURE MSR Heatin Steam Su a.
e osed, b.
TRANSFER the Auxiliary Steam System steam ag pl to the Auxilian Boiler e
per 13761, y' Auxiliary Steam System",
Q, TN "
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c.
TRANSFER the Turbine Steam Seal suppl to the Auxiliary Steam Supply per 1 825, " Turbine Steam Seal
%{h System",
1 d.
TRANSFER the SJAE steen supply to the Auxiliary Steam Supply per 13620, A yj!
" Condenser Air Ejection System".
L If'M in Generator is to be shut down j
a e.
i for more than two days, then to prevent overheating relay 360A, OPEN links TBR'28, 29 and 30, located in Protective Relay Panel Bay 4, per 00306-C, " Temporary Jumper And Lifted Wire Control",
-is. n.
f.'
If the Generator Regulator Panel i
(1328-P5-GRC) is to be de-energized for maintenance, then OPE links TBR 56 and 57 and TBS 4 and 5 located in Protective 1
l Relay Panel Bay 4, per 00306-C,
" Temporary Jumper and Lifted Wire t
Control".
This'will prevent tripping Lockout Relays 386 G9 and
/V g, A/
386 G10 which trip Generator Output Breakers.
i 3
At the Main Transformer Control l
Cabinets, de-energize the Transformer Oil Pumps and Fans per Sub-subsection 4.3.1. peration" 13800, " Main Turbine O L
Pope 6 1'
MsVfS6oN GME NO.
pnocsount No.
VEGF 12006.,
10 10 of 52 1
INITIALS 4
A4.1.3 At the USS's discretion, DISABLE the MFPT trip circuitry to AWAS by removing
- j and tagging the following fuses:
I a.
TRAIN A 4
Auxiliary Relay Panel - Fuse Block (Inhibits MFFT trip signal to initiate AWAS),
j l
UNIT 1 UNIT 2
- -7 l
INCPAR-2-FU-4 2NCPAR-2-FU-4 J !/.i A-Q%k I
IV b.
TRAIN B Auxiliary Relay Panel - Fuse Block i
(Inhibits MFPT trip signal to initiate AFWAS),
l UNIT 1 UNIT 2
~...
J36
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INCPAR-4-FU-1 2NCPAR-4-FU-1 Wk IV i
A4.1.4 Either OPERATE unit systems as necessary to maintain the unit at Hot Standby, or PROCEED to either Section B to initiate unit cooldown or 12003-C, " Reactor Startup" t
to' return to power.
END OF SECTION A t
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VEGP 12006-10 11 of 42 1
SECTION B:
Cooldown to not less than 350' F NOTE This section directs cooldown to 375"F or any point between without crossing the boundary i
for Mode 4 at 350'F.
B4.1 PREPARATION FOR UNIT COOLDOWN INITIALS i
B4.1.1 If required to cooldown secondary systems, then INITIATE Section E of this procedure.
j B4.1.2 If Condenser vacuum is being maintained, then INITIATE placing a steam blanket on Operation"per 13800, " Main Turbine b/A the MSR's B4.1.3 INITIATE pressurizer and RCS boron equalization by energizing Pressurizer Backup Heaters.
4 j
B4.1.4 MAKIMIZE CVCS letdown purAfication
- f10wrate, t -'1 f'l / / 87 3 G-date'/ time 7
B4.1.5 INITIATE Borating the RCS to the cold shutdown boron concentration per 13009, "CVCS Reactor Makeup Control System".
If applicable, PERFORM 14835, " Boric Acid Injection Check Valve Cold Shutdown
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Inservice Test" during the boration.
B4.1.6 DIRECT Chemistry to sample the RCS and
/
Pressurizar boron concentration.
P 1
B4.1.7 If withdrawn, INSERT all Shutdown bg Banks to the fully inserted, position.
B4.1.8 OPEN the Reactor Trip breakers.
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INITIALS 84.1.9 If not currently in progress, INITIA2*E RCS gaseous activity degas by performing the following:
a.
ENSURE that the Pressurizer Steam Space Sample line is in operation by verifying that the.PRZR STM SAMPLE IRC/ ORC Valves HV-3513/MV-3514 are Q
- open, b.
NOTIFY Chemistry to adjust the pressurizer steam space sample flow rate to maximum, I
c.
While maintaining hydrogen cover
)
gas, DEGAS the RCS by raising VCT gas purge flow rate to the Gaseous Waste Processing System HIC pproximately 1.2 scfm using to aA094, as limited by the Hydrogen Recombiners.
84.1.10 When notified by Chemistry that the RCS gaseous activity has been reduced to an acceptable level, TRANSFER VCT cover gas to Nitrogen and INITIATE RCS Hydrogen degas per 13007, "VCT Gas Q,
Control And RCS Chemical Addition".
NOTE l
Prior to opening the RCS to containment the hydrogen concentration shall be less l
~
than 5 cc/kg.
i i
B4.1.11 START both containment Pre-access Filter CTB PREACCESS FLTR UNIT-1/2 Units using/2621.
/-6-Pi Nr /
FAN HS-2620 date/ time i
B4.1.12 If it is planned to cool down to Cold Shutdown, and if not performed in the grevious three months, COMPLETE 14743, AFW Check Valve Shutdown Inservice A jA Test".
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5.svison VEGP 12006-C 10 13 of 42 2
1 INITIALS 54.2 RCS C00LDOWN TO 375'F j
B4.2.1
- COMGENCE RCS/ Pressurizer pressure and temperature trending at 30 minute intervals using Data Sheet I and ERF i
computer.
(Technical Specification j
4.4.9.1) i Data taking and plotting may be i
i suspended during holds in the cooldown if the duration is expected i
i to exceed one hour.
NOTE 3
It is recommended that the j
RCS temperature be maintained i
between 75' F and 125' F less l
than pressurizer temperature.
l (See Figun 1.)
COMENCE the cooldown to 375'F and 540 B4.2.2 psig at a recommended rate of 1
approximately 50*F per hour by performing the followings REDUCE the number of operating RCPs a.
to two per 13003, " Reactor Coolant l
Pump Operation",
c g i.
Pumps 4 and 1 are the preferred running pumps, i
b.
INITIATE Pressurizer cooldown and
)
l depressurization by slowly opening g
the Pressurizar Spray valves, i
If necessary, selectively DE-ENERGIZE Pressuriser Back-up Heaters by placing control Switches to PULL-TO-LOCK, i
CAUTION I
RCS traperature and pressure shall 2e maintained within the a<ceptable operating region of Figure 1.
Slowly ADJUST the Steam Dump controller I
c.
setpo:.nt or if applicable the l
Atmospheric Relief Valves to initikce 3
RCS cooldown.
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VEGP 12006 10 14 of 42 1
INITIALS SHV-8gstg,OBSERVEPRZR 4
2185 Ataphroximate B4.2.3 00A and HV-80003 PORV LOCK VAL 4
auto close.
NOTE i
Depending on the rate of RCS cooldown and depressurization, Step B4.2.5 may occur before i
Step B4.2.4.
j f
l B4.2.4 At approximately 550*P RCS temperature PERPORM the followings i
i VERIPY status light LO LO TAVG TRAIN
{
s.
A STEAM DUMP INTL P12 illuminated, i
b.
BYPASS the LO LO TAVG interlock by momentarily placing the Train A and B Steam Dump Interlock Selector Switches to the BYPASS INTERLOCK
(
l
- position, r
If operating on Steam Dumps, then VERIFY Steam Dump Cooldown Valves PV-0507A,B and C are open by i
observing ZLB-2 on QMCB,
^
CAUTION r;.
If the RCS is allowed to pressurize above Pil and SG pressure is below 585 psig, Safety Injection and Steam i
Line Isolation will occur.
4 B4.2.5 At approximately 1970 peig, manually BLOCK j
Pressuriser Pressure and Steam Line Pressure Safety Injection and Steam Line Pressure -
t
. Steam Line Isolation signals by performing the following:
i It is is planned to cool down for a.
refueling, then PERPORM 14710,
" Remote Shutdown Panel Transfer Switch And Control Circuit 18 Month Surveillance Test" Data Sheets 3A l
and 3B in lieu of the following l
- substeps, J
b.
VERIFY Block Permissive Status Light r
PRZ1 LO PRESS SI BLOCK PERM P11
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j illuminates, i
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i VEGP 12006-10 15 ef 42
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INITIALS 1
c.
BLOCK the Low Pressurizer Pressure
)
Safety Injection signal using PRZR PRESS SI BLOCK / RESET A and B F
handswitches HS-40012 and 40013, 4
d a
j d.
OBSERVE Status Lights PRZR TRAIN A/B SI BLOCKED illuminated,
. BLOCK the Low Steen Line Pressure e.
Safety Injection si 1 using LOW-STM PRESS SI/SLI B K RESET handswitches HS-40068 and 40069, l
f.
OBSERVE Status s STMLINE ISO
(
TRAIN A/B SI B illuminated.
B4.2.6 CHECK that Pressurizer level is between 201 and 401.
1 i
B4.2.7 As RCS pressure lowers, OPEN additional Letdown Orifice Isolation Valves and
)
ADJUST PIC-131 setpoint to maintain
~
desired letdown flowrate.
i B4.2.8 During RCS depressurization, MAINTAIN all RCP seal injection flow rates between 8 Header Flow controller HC-0182. ging and 13 spa by adjusting the Char 2
4 l
B4.2.9 At approximately 950 pais, ISOLATE ECCS Accumulators by performing the following:
i l
a.
REMOVE TAG, UNLOCK and CLOSE the Accumulator Discharge Isolation Valve I
480V MCC Breakers:
i UNIT 1 UNIT 2 ACCUM-1 1ABE-19 2ABE-19 b
ACCIM-2 IBBC-19 2BBC-19 6
ACCUM-3 1ABC-19 2ABC-19 b
ACCUM-4 1BBE-19 2BBE-19 b
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VEGF 12006-v 10 16 of 42 INITIALS b.
CLOSE the Accumulator Isolation Valves, ACCUM-1 HV-8808A, h
ACCUM-2 HV-88088, b
k ACCUM-3 HV-8808C, ACCUM-4 HV-8808D.
d c.
VERITY annunciators ACCUM TANK 1(2,3,4) ISO VLV 8808A(B,C,D)
NOT FULLY OPEN in alarm.
ALB06-A05,505,C05,D05,
/L/-9
- d.'
OPEN, LOCK and TAG the Accumulator Discharge Isolation Valves 4807 NCC
ACCUM-3 IABC-19 2ABC-19 GiW IV ACCUM-4 IBBE-19 2BBE-19
^
+
p en~T IV B4.2.10 When steam pressure falls too less i
than 550 pair, at ths USS's discretion the Steam Generators may be supp' lied by the running Condensate Pump per Section E4.2 of this procedure.
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nevislON lPAGENO.
VEGP 12006 10 17 Of 42 INITIALS 34.2.11 Either OPERATE unit systems as necessary to maintain RCS within the following
. parameter values or PROCEED to either
'Section C to continue the cooldown or 12002-C, " Unit Heatup to Normal Operating Temperature and Pressure" to cotanence a heacup.
RCS temperature 375'F *10'F RCS pressure 540 psig *25 ps g Pressurizer level at program leve END OF SECTION B 1
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VEGF 12006.
10 18 of 42 I
SECTION C:
Cooldowd to not less than 205'T i
NOTE 4
This section directs cooldown to 225'T or any point between i
without crossing the boundary for Mode 5.
C4.1
, PREPARATION FOR CONTINUING UNIT C00LDOWN.
INITIALS i
l C4.1.1 If required to cooldown secondary systems and break condenser vacuum, then INITIATE SECTION E of this procedure.
CAUTION i
Maintain pressurizer cold l
calibration level greater than 171.
t l
C4.1.2 If it is planned to cool down to cold shutdown, then ALLOW pressuriser level to rise during the cooldown to not I
greater than 80% cold calibrate.
C4.1.3 COMMENCE RCS/Pressurizar pressure and temperature trending at 30 minutes intervals using Data Sheet 1 and ERF computer.
(Technical Specification 4.4.9.1)
Plotting may be suspended during holds in the cooldown if the I
du' ration is expected to exceed one hour.
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VEGP 12006 10 19 of 42
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1 INITIALS C4.2 RCS C00LDOWN TO 225'F.
NOTE It is recommended that the 1
RCS temperature be maintained between 75*F and 125'F less than pressurizer i
temperature.
(See Figure 1.)
3 C4.2.1 CO)tENCE the cooldown to 225'F and 250 psig at a recotenended rate of approximately 50 F per hour by performing the following:
i i
CONTINUE the pressurizar cooldown and i
a.
depressurization by slowly opening the Pressurizer Spray Valves, Cn If necessary, selectively DE-ENERGIZE Pressurizar Backup Heaters by placing Control Switches to PULI LOCE,
CAUTION
~
t l
RCS temperature and pressure shall be maintained within the acceptable operating region l
of Figure 1.
y b.
Slowly ADJUST the Steam Dump controller Setpoint or if applicable the Atmospheric Relief Valves to i
i initiate RCS cooldown.
l C4.2.2 If it is planned to cool down for refueling,UEST confirmation fromthen prior to reaching i
i 350*F, REQ Engineering / Maintenance that actions i
have been taken to preclude Reactor A. 4-i Vessel Seismic Tie Rod Binding.
t..
e-l C4.2.3 Frior to reaching 350*F, NOTIFY Chemistry to isolate PERMS CVCS
? / '
i Letdown Monitor RE-48000. g (g,,.
l i
l l
l
..__..m.
4 t.
MnocsDuns No.
nsvassON v Aut, NO.
4 I
VEGP 12006-C 10 20 of 42 k.
L INITIALS
!^
.i i
C4.2.4 Prior to reaching 350'F, PLACE the Cold Overpressure Protection System (COPS) in
. operation by performing the following:
If not performed in the previous i
a.
three months, PERFORM 14860, j
"PORY Cold Shutdown Inservice I,..,
Test",
b.
ARM the A and B COPS by placing the PRZR FORY BLOCK VLV COLD i
OVERPRESSURE CNTL handswitches HS-8000G and 8000H to the ARM i
i.
- position, VERIFY the following annunciators j
c.
alarmed upon arming CONS:
a l
A COLD OF ACTU VLV HV-8000A NOT i
FULL OPEN (ALB12 E06),
L >' -
B COLD OF ACTU VLV HV-80005 NOT -
FULL OPEN (ALB12 F06),
4 l
d.
ENSURE PRZR PORVs PV-455A and 1-PV-456A s.re closed and the l
handswitches in AUTO, ENSURE OPEN PRZR PORY BLOCK i
e.
Valves HV'8000A and 8000B, a
NOTE Step f satisfies Technical Specification surveillance t
4.4.9.3.1.c h
f.
VERIFY the following annunciators 4
i reset n
A COLD OF ACTU VLV HV-8000A NOT 4
FULL OPEN (ALB12 E06),
/
B COLD OF ACTU VLV HV-80005 NOT FULL OPEN (ALB12 F06).
4 C4.2.5 At 350*F, LOG time and date of entry into Mode 4 in the Unit Control Log Book.
thch9 ccW l'
' date/ time
'o J = $~~rie w '.'= -*
\\ c r o., i'.~. y A
juy)O h: p e,-
fb"~W'r I* h I ' ~
f 94.rd Lc0
} - f t) C V c -4 < r - t. e<
seen.
i
QEVISION WAQf, NQ.
I'
' PROCEDURE NO.
VEGP 12006-t, 10 21 of 42 INITIALS C4.2.6 Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after entering Mode 4 and prior to reaching 325'F PERFORM the j
followings i
1 RACK OUT and TAG both safety a.
Injection Pump Breakers, UNIT 1 UNIT 2 SI PMP-A 1AA02-16 2AA02-16
'n.
NOTE AFWAS sbcald be defeated to the SG Blowdown Valves, Ssample Valves and MDAFW Pump Discharge Valves to accommodate MFP activities and/or SG draining /
filling operations without.
resulting in impacting those activities.
b.
At the USS's discretion. REMOVE and TAG the following fuses:
(1)
Train A Auxiliary Relay Panel -
Fuse Block (Allows full use of SG Blowdown valves),
I UNIT 1 UNIT 2 1ACPAR6-FU-2 2ACPAR6-FU-2 de J. '
IV aiin >
1 1
vuese
~MeoCEDURE NJ.
REV8860N pr4E NO VEGP 12006 10 22 of 42 INITIALS e
i (2)
Train B Auxiliary Relay Panel -
~
Fuse Block (Allows full use of SG Blowdown valves),
UNIT 1 UNIT 2 1
IBCPAR7-FU-6 2BCPAR7-FU-6
'/
A:
I IV l
- c.. PIACE standby MDAPW Pumps handswitch g
in PULL-TO-LOCK.
4 d.
If the TDAFW Pump is not being utilized, CLOSE HV-5122, 5125, 5127 and 5120.
(Ak i
h O
J k
i a
e S
Y M
4
4 pmoceou.,a wo.
uvoow not wo.
VEGF 12006 o 10 23 of 42 i
INITIALS i
C4.2.7 When the RCS pressure-is less than 365 i
psig, and RCS temperature is less than i
340 F, PLACE at least one RHR Train in operation per 13011, " Residual Heat e'
4 Removal System".
/
OPERATE RHR HX Outlet Valves a.
HV-0606(0607) and Bypass Valves FV-0618(0619) to control RCS temperature as necessary and RER flow at a minimum total flow of i
i 3000 gym, 4
4 1
b.
If applicable, PERFORM 14896, i
"ECCS Check Valve Cold Shutdown, gpr N
Inservice Test",
i ENSURE RHR Suction Isolation c.
surveillance is initiated each J
shift per 14000. " Shift And Daily Surveillance Logs".
hd //
i i
CAUTION
,2 While in Mode 5 with the Reactor Coolant Loops filled, with 1 RER Train inoperable, the secondary side water level of at least two l
Steam Generators shall be greater than 17% WR.
l C4.2.8 If desired, REDUCE the number of operating RCPs to one per 13003, " Reactor Coolant 3'v -
Pump Operation".
Pump 4 is the preferred running pump to ensure best spray capability.
CA.2.9 When SG pressure falls to 25 psis per 13601, "gning Nitrogen to the SG's INITIATE aliSteam Generator And Main l
Steam System Operation" with regulators set at 2 to 5 psig.
i C4.2.10 If it is intended to perform maintenance ou the RAT's during the outage, then NOTIFY Maintenance to initiate work towards backfeeding through the Main YA&
Transformer and UAT's.
G e
- ~ -, -
'pnOCEDuas NO.
REVISION
- cA&E NO.
VEGP 12006-v 10 24 of 42 INITIALS C4.2.ll Either OPERATE unit systems as necessary to maintain RCS within the following
. parameter values or PROCEED to either Section D to continue the cooldown or 12001-C, " Unit Heatup to Hot Shutdown" to consnence a heatup.
CAUTION Ensure rumsing RCP seal differential pressure is maintained greater than 200 paid.
s RCS temperature 225 F *10*F RCS pressure 250 psig *25 psig i
END OF SECTION C 3
i 4
4 i
4 t
i 9
i i
'e M
4 enocsouns no.
naviseow ivaos no.
VEGP 12006..
10 25 of 42 l'
-i SECTION D Cooldovrf to Cold Shutdown (less than 200*F).
4 NOTE This section directs cooldown to Mode 5 and maintains tem >erature between 130*F and i
80*T.
D4.1 PREPARATION FOR CONTINUING UNIT C00LDOWN INITIALS I
D4.1.1 If required to cool down secondary systems and break condenser vacuum, then INITIATE Section E of this. procedure.
4' i
D4.1.2 COMtENCE RCS/ Pressurizer pressure and a
1 temperature trending at 30 minute intervals using Data Sheet 1 and ERF l;
Computer.
(Technical Specification 4.4.9.1) 4 1
Plotting may be suspended during holds in the cooldown if the duration is expected to exceed one hour.
/,//
?
D4.1.3 ENSURE RHR letdown is in operation with
/ t &_
flow rate greater than or equal to 75 spa.
i D4.2 RCS C00LDOWN TO BEIVEEN 130*F and 80'F
)
D4.2.1 COMENCE the cooldown at a recommended rate of approximately 50*F per hour by j
performing the following:
Slowly ADJUST the RRR Outlet Valves a.
i HV-0606(0607) to reduce RCS y
"Q temperature,
/1 CAUTION
/
i l
Ensure running RCP seal differential pressure is i
maintained greater than i
200 paid.
b.
MAINTAIN Pressurizer pressure at 250 psig, *25 psig,kup Heaters.
/ /'.p-by selective use of Pressurizar Bac l
i i
~'
t puest t
i
_ =..
MtoCEDURE No.
Arvai4CN NAGE No.
l VEGP 12006-v 10 26 of 42 l
INITIALS I
D4.2.2 At 200*F, LOG time and date of entry into Mode 5 in the Unit Control Log sook.
/
P.VZ f 149 ff
\\
time /date D4.2.3 RACK OUT and TAG the Containment Spray pump breakers.
1 UNIT 1 UNIT 2 CS PMP A 1AA02-14 2AA02-14 I
D4.2.4 As directed by the USS, PLACE the Containment Pre-access Purge System Purge System"per 13125, " Containment in operation D4.2.5 To facilitate personnel ingr. ass and egress, during cold shutdown, NOTIFY Maintenance to bypass the Containment i
Personnel Lock Interlock System.
1 If desired the Containment Equipment Hatch Missile Shield may be moved at l
this time.
D4.2.6 NOTIFY Work Planning Group to schedule and initiate mode dependent Fire 6
D 1
Protection Surveillances.
j D4.2.7 When the RCS temw rature is less than 140*F, PERFORM tse following a.
If withdrawn, INSERT all Shutdown Q
j Banks to the fully inserted position, 4
b b.
OPEN the Reactor Trip Breakers, STOP the dkDM Cooli Fans using thefollowinghandsNtches:
c.
i CRDN UNIT - FAN 1 HS-1227'3A, CRDN UNIT - FAN 2 HS-12274A, CRDN UNIT - FAN 3 HS-12275A, CRDN UNIT - FAN 4 HS-12276A.
1 d.
If it is intended to remain in cold PLACE the SG' greater than 4 days, then shutdown for I
s in wet layup per 13601,
" Steam Generator and Main Steam System
?
Operation".
1-w lL
_ - ~ - -., -,
e-a
-..-.---.w
.-a.
a--,
+.a
- - +.. -
- ~. -
Paocsouma wo.
tawsooN POat NO.
VEGP 12006-i 10 27' o'f'42 e
a.
INITIALS g
j NOTE i
The RCP(s) shall be run for one or more hours after reaching j
the desired RCS temperature plateau to enhance SG and RCS Q
temperature equalization.
d j
D4.2.8 When RCS temperature is less than 110'F, the remaining RCPs may be stopped per i
13003, " Reactor Coolant Pump Operation".
i D4.2.9 If it is desired to collapse the pressurizer bubble and cooldown the l
pressurizer, then PERFORM the following:
a.
ENSURE all CVCS Letdown Orifices are l
in operation.
1 i
. CAUTION 1
Expect rapid pressurizer pressure rise with charging flow greater than letdown flow at the point of going.
solid.
Be prepared to reduce charging flow or raise letdown i
flow to prevent extreme pressure fluctuations.
b.
RAISE pressurizer level by raising h
charging flow rate and/or lowering RHR letdown flow rate, i
c.,
When the pressurizer is solid as indicated by rising RCS pressure or if FIC-131 is in AITIO rising letdown l
flow rate, then PERFORM the following (1)
BALANCE charging and letdown flow rates using HV-0128 4
and/or PIC-131 to maintain RCS qC-pressure at 250 psig *25 psig.
e i
l i
L Feense f
pnocsouns wo.
xavisson paos na, i
VECF 12006-10 28 of 42 I
.I INITIALS I
NOTE 1
i Charging flow may remain greater than letdown flow as a result of 1
I coolant contraction during the I
cooldown.
(2)
Chargig/RNR letdown flow rate should be adjusted so that RHR letdown purification flow is maintained greater than or equal to 75 gym,
/.
i (3)
OPEN Pressurizar Auxiliary Spray valve HV-8145.
[.,,"-
i l
(a)
INITIATE AUX SFRAY/PRZR DELTA-T surveillance per 14915, "Special Conditions
(
i Surveillance Logs",
(Technical Specification f-i 4.4.9.2),
e /, y m.
l j
(b)
If pressuriser auxiliary spray water delta-T exceeds j
320 F, then LOG the spray valve operation in the Unit Control Log and NOTIFY Engineering to log the cycle per 50040-C, " Component i
Cyclic or Transient LLaits",
(, ~~
i (4)
CLOSE the open Charging Isolation Valve HV-8146 or HV-8147, C3 V" (5)
Continue CHARGING through the pressurizer auxiliary spray line i
until pressurizar steam space
/~
s, temperature is less than 190*F.
Yv D4.2.10 MAINTAIN RCS tserzerature between 130'F and 80*F using RIK HX Dutlet Valves
,s i
E-KV-0606(0607).
NOTIFY Engineering to log the unit cooldown per 50040-C, " Component
/_.
i Cyclic or Transient Limits '.
l i
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- ~
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emoceouns wo.
navision
'caose+o.
VEGP 12006-t, 10 29 of 42 i
INITIALS I
CAUTION Ensure all RCP's are shutdown.
D4.2.11 If it is desired to depressurize the RCS, then PERFORM the following:
a.
INITIATE Lowering RCS pressure to atmospheric (50 psig as indicated on PI-408, 418, 428 or 438) using
/e \\ ' '
1 letdown pressure control PIC-131,
./
l b.
When RCS pressure reaches 100 psig (150 psig as indicated on PI-408, 418, 428, 438), CLOSE all RCP Seal a
f Isolation valves HV-8141A, sp, -
ENSURE PRT nitrogen pressure is maintained greater than 0.5 psig.
.0/b '
c.
4 i
NOTE SI Pap Cold Leg Isolation Valves are closed to preclude inadvertent draining of RWST to the RCS while the RCS is depressurized and partially drained.
I D4.2.12 ISOLATE the Safety Injection Cold legs by performing the following:
f CLOSE SI PHP-A TO COLD LEG ISO VLV a.
P-HV-8821A, b.
CLOSE SI PMP-B TO COLD LEG ISO VLV f.
HV-88215, OPEN and TAG the following SI Cold Lag Isolation Valvas MCC breakers:
c, UNIT 1 UNIT 2 (1)
SI PMP-A TO
- ~
COLD LEG ISO VLV HV-8821A, IABD-15 2ABD-15 f,/ '.
3 5-i l
(2)
SI PHP-B TO COLD LEG ISO-l VLV HV-88215.
1BBD-15 2BBD-15 p-meses
~
- nocsouaa wo.
taviseow
%s no.
VEGP 12006-c 10 30 of 42 1
INITIALS e
CAUTION i
Prior to opening the RCS to the containment atmosphere, the RCS hydrogen concentration shall be j
[-
1ess than 5 cc/kg.c r u,e.W i
~, jg,, ).,,. -, ~ <,.n '
.Y ", e
- v D4.2.13-When required, INITIATE RCS draining by performing the following:
i If it is intended to drain down to l
a.
i perform maintenance on Reactor Head, SC's or RCP seals, then the following j
RCS level controls should be placed
.I into.effect:
I (1)
If it is intended to operate at one foot above mid-nozzle i.
level, the preferred RER configuration is one train i
operating with a flow of 3000 pl j
- gym, i
(2)
If it is intended to operate at one foot above mid-nozzle j
level, a minimum of two incore l
thermocouples should be d
available during periods where
,u the Reactor Read is installed, (3)
IEC should be notified to install temporary remote RCS level monitoring in the g
Centrol Room, i
(4)
Tyson tube watch is required i
any time the RCS level is i
being changed while the RCS i
level is below 17%
(approximately 207 feet
\\g elevation) pressuriser level.
A t
(5)
Periodic comparison checks should be made every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> between the Control Room Temporary RCS 1.evel Monitors egg and the Tyson tube, I
(6)
The Control Room Monitors should agree within 2 percent of scale with the Tyson tube, t
sense
~
m
hace no.
naymon enocaouas no.
VEGP 12006 w 10 31 of 42 I
l, INITIALS (7)
Two out of three Level Monitors must agree before draining RCS below the top of the hot leg (188 feet 3 inches),
~
(8)
If neither Control Room RCS Level Monitor is available, then a continuous Tyson tube watch should be established while RCS level is below 17%
A'Igy, pressurizer level, J'
(9)
While operat W with Steam Generator Nozzle Dans installed, ENSURE one Safety Injection Pump i
is capable of being racked in and operated if needed, i
i (10) While level is in the region of the hot legs, TREND RNR %
Parameters on ERF for early detection of possible RER %
i degradation due to vortering, i
i (11) Minimus RCS level is one foot l
above mid-nozzle (188 feet 0 inches elevation) except for i
Steam Generator burping during i
initial drain down.
For l
effective SG tube draining, RCS j
I level should be lowered to l
187 feet 6 inches.
Upon i
completion of SG burping, RAISE RCS level to 188 feet - 0 inches h
and MAINTAIN at this level p
thereafter, i
(12) INITIATE draining the RCS per 13005, " Reactor Coolant i
System Draining".
l l
l l
l i
{
mpe I
4 aos no.
- nocsouns wo.
navmow VEGF 12006-c 10 32 of 42 y
INITIALS If it is intended to drain the RCS to less D4.2.14 than 25I cold calibrate pressurizer level,
.then prior to reaching 25% ISOLATE potential dilution flow paths by performing the following:
CLOSE, IACK and TAG the following j
a.
valves 4
i (1)
UNIT 1:
CVCS ISOLATION k
i RMW TO BA BLEND, p
l 1-1208-U4-175
~l 1
J UNIT 2:
CVCS ISOLATION RMW TO BA BLEND, 1
2-1208-U4-175
,4.A
- i i
i (2)
UNIT 1:
CVCS ISOLATION RMW TO CVCS, M4 i
1-1208-U4-177 I
i UNIT 2:
CVCS ISOIATION RMW TO CVCS, 8 g A' 4
j 2-1208-U4-177 l
l b.
ENSURE CLOSED, LOCEED and TAGGED the i
following valves:
l (1)
UNIT 1:
CVCS OUTLET CHEM MIXING TK, 81 tS 4
1-1208-U4-1 N
i i
UNIT 2:
CVCS OUTLET CHEM i
A MIXING TK, 81 MM 2-1208-U4-1 (2)
UNIT 1:
CVCS SUPPLT RMW TO CHEM MIXING TK, A
1-1208-U4-176
- i UNIT 2:
CVCS SUPPLT RHW TO CHEM MIXING TK, g'
2-1208-U4-176 1
i j
i e
A- -
enoesouns wo.
6;rviseow i,.aos wo.
VEGF 12006-c 10 33 of 42 i
1 INITIALS I
,i j
(3)
UNIT 1:
CVCS FLUSH RMW TO TRN A EMERG j
- BORATION, Mp 1-1208-U4-183 i
f UNIT 2:
CVCS FLUSH RMW TO TRN A EMERG 1l BORATION,'183 4
2-1208-U4-M F i
1 (4)
UNIT 1:
RMWST TO BTR5 ISO, 1-1208-U6-226 A(M UNIT 2:
RMWST TO BTRS ISO, A(y 2-1208-U6-226 4
makeup to the VCT by When necessary,following:
i c.
performing the f
(1)
OPEN RWST TO CCP A & B SUCTION Valves LV-0112D and LV-0112E, 4
(2)
CLOSE VCT OUTLET ISOLATIONS, LV-01125 and LV-0112C, 1
i (3)
ENSURE Letdown to VCT or Bold-up Tank Valva LV-0112A is in the i
VCT position, i
i i
(4)
When.VCT level has been returned to normal, OPEN LV-01125 and l
LV-0112C then CLOSE LV-0112D and LV-0112E.
D4.2.15 OPERATE unit systems as necessary to
)
maintain the above conditions.
i a.
If required to break condenser l
vacuum, then PROCEED to Section i
E, b.
If it is intended to proceed to Mode 6, then GO to 12007-C,
" Refueling Entry",
If it is intended to commasace unit c.
heat up, then Go to 12001-C, " Unit Heatup to Hot Shutdown".
4 END OF SECTION D s
4
vnocaouns wo.
neveon uos no.
-VEGP.
12006-u 10 34 of 42 1
1*
1 SECTION E.
Seconda/y Plant Shutdown t
NOTE This section directs secondary 4
plant activities during unit i
shutdown and can be used in S
conjunction with primary system cooldown operations.
1 The subsections of this section ares l
E4.1 Transfer From Steam Dumps to Atmospheric Relief valves.
E4.2 Feeding Steam Generrtters With j
Condensate Pump.
E4.3 Breaking condenser vacuum.
E4.4 Secondary Systems activities.
4 l
E4.1 TRANSFER FROM STEAM DUMPS TO ATMDSFRERIC i
RELIEF VALVES INITIALS 1
E4.1.1 TRANSFER to the SG Atmospheric Relief Valves J
by performing the following f
a.
Slowly OPEN each atmospheric relier while verifying a reduced steen dump demand signal on f,N UI-507, b.
VERIFY that the Steen Dump Control Valves close if FIC-507
~
is in AUTO or if operating in MANUAL, slowly CLOSE the Steen Dump control Valves j
while opening each atmospheric
- relief, T
1 i
c.
When all Steen Dump Control Valves are closed, ENSURE FIC-507 is in MANUAL,
?
l d.
BALANCE the positions of each atmospheric relief while l
maintaining Tavg as desired.
p "'
i l
I
=
i,aos wo.
paoceovas no.
aavism VEGP 12006 o 10 35 of 42 l
i
\\
INITIALS FEEDING STEAM GENERATORS WITH CONDENSATE E4.2 PUMP E4.2.1
'At the USS's discretion, INITIATE feeding Steam Generators with the running Condensate Pump by performing the following:
VERIFY SG pressure is less than
- 2. ' /-
i a.
550 psis, f
i b
VERIFY that lube oil pressure to the reset MFP and MFP Turbine Fearings is 10 to 12 psig by local indicaeions, i
OPEN the reset MFP Discharge Valve c.
i by placing the Control Switch in I
OPEN-FULL-TO-IACK at the Main l
Control Panel QMCB:
t SGFP A HS-5208, 1
SGFP 5 HS-5209.
d.
If not previously performed, RESET both trains of Feedwater Isolation:
(1)
RS-40049 for Train A, (2)
HS-4dO50 for Train B.
OPEN all BFIV's, e.
f.-
CONTINUE maintaining desired SG 1evel utilizing the BFRV's.
+
4
- a. -
w=w wo.
Leview:m j ews,.o.
VEGP 12006 10 36 of 42 INITIALS E4.3 BREAKING CONDENSER VACUUM j
E4.3.1 If necessary, TRANSFER the Auxiliary
- Steam System steam supp y to the Auxiliary Boiler per 13 61, " Auxiliary 3
Steam System".
's i
E4.3.2 TRANSFER the Turbine Steam Seal su
[',)
l to the Auxilia Steam Supgly per 5,
" Turbine Steam eal System E4.3.3 TRANSTER the SJAE steam supply to the i
Auxiliary Steam Supply per 13620, J
" Condenser Air Ejection System".
- l
//M E4.3.4 CLOSE the MSIVs and Bypasses.
CAUTION Breaking condenser vacuum j
will result in a MFPT Low i
Vac Trip.
If AFWAS has not been defeated, then both 1
l MFFs tripped will result in a AFWAS initiation.
i E4.3.5 PLACE the standby MDAFW (s)
(
1 Handswitches in PULL-TO-y l
E4.3.6 BREAK condenser vacuum and SEUT DOWN the Steam Jet Air Ejectors and the i
Condenser Vacuum Pumps per 13620,
" Condenser Air Ejection System".
t i
E4.3.7 PERF0hlM the following to reset the i
AFWAS signal:
i a.
RESET the AFWAS by resetting one MFPT Low Vacutan Trip y l
momentarily placing e MFFT-A(B)
VAC TRIP BYPASS Handswitch to RESET position and MFPT A(B)
TRIP RESET HS-3169 (3170) to the
/
RESET p~o'sitica, e
b.
If running a MDAFW Pump, then THROTTLE the AFW Flow Control Valves to the pre-initiation f7,
/'
j flow rate, EA yl&YffYYY Y
Y meae 1
J
MtoCEDuM No.
MVISloN
- AGE NO VEGP 12006-C 10 37 of 42 1'
INITIALS c.
If applicable, ENSURE the SG Blowdown Isolation Valves
/Vd i
HV-7603A(B,C,D) open.
n l
E4.3.8 After the condenser' pressure reaches atmospheric, SHUT DOWN the Turbine Steam J
4 Seal System per 13825, " Turbine Steam
,f Seal System".
E4.3.9 MAINTAIN the main Turbir.e and MFPTs on Turning Gear per 13800, " Main Turbine Operation" and 13615, " Condensate and j
Feedwater Systems".
l E4.4 SECONDARY SYSTEM ACTIVITIES 4
E4.4.1 If condensate and feedwater cleanup is not anticipated, then when condensate and feedvater metal tem >eratures are less than 200*F, SHUT DOWN t se Condensate and i
Feedwater System per 13615, Condensate Mk 4
And Feedwater Systems".
i l
E4.4.2 NOTIFY Chemistry and SHUT DOWN the Condensate Filter Domineralizar System per 13616, " Condensate Filter rd 4 Domineralizer System".
j E4.4.3 If the secondary outage is ?lanned to exceed 10 days, then PERFORM the l
following:
l a.
When condensate and feedwater metal tangerature is between 90*F and 200 F, COORDINATE with Chemistry and i
CE the Feedwater Heaters in vet g
b.-
When Turbine metal temperatures reach ambient, REMOVE Turbine from Turning Gear per 13800, " Main hl k Turbine Operation",
j During the unit outage, once a week, c.
FLACE the Turbine on Turning Gear 4
for 4 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
l 9
4 M
l
l MtoCsDURE No.
LEVIS 8oN
'paog no.
VEGP 12006-s, 10 38 of t.2 l-ie l
INITIALS l
E4.4.4 If required, PLACE a steam blanket on the MSRs per 13800, " Main
'u 4-i
, Turbine operation".
a
)
E4.4.5 If required, for Condenser Waterbox or Circulating Water System maintenance, SHUT DOWN the Circulatin Water System per13724,"CirculatinghaterSystem".
c'L ( 4 1
If required for maintenance or inspection, then INITIATE draining of the Condenser Waterboxes per ol #
13724, " Circulating Water System".
E4.4,6 If main generator maintenance or 1
inspection is planned, then INITIATE the main generator per p.-l P l
purging" Generator Gas System".
13810
,1
~
4 If hydrogen atmos 7 ere is to be h
maintained, then :(INIMIZE usage during the outage by reducing i
i hydrogen pressure to not less than 5 psig.
l E4.4.7 SHUT DOWN the Isophase Bus Duct Cooling t
System by performing the following:
Isophase Bus Duct Heater Breaker p i R--
)
UNIT 1:
1NB03-16, c
}
UNIT 2:
mi&
4 i
b.
At local Panel PLCB, STOP the running fan using MS-16550 for Fan'No. I and/or HS-16551 for Fan No. 2.
i Completed
/4Ab '
. [t1 Ef I / d T~
signature Date/ Time
/ /ta l/9 I l#Y"~
Reviewed A(JM2- -
signature Date/ Time t.
4 pusset Y
~
pnoceouna No.
navisos paosno.
.VEGP 12006-10 39 of 42 5.0 REFEREdCES 5.1 PROCEDURES 5.1.1 10006-C,
" Reactor Trip Review" 5.1.2 12001-C,
" Unit Heatup To Hot Shutdown" 5.1.3 12002-C,
" Unit Heatup To Normal Operating' Temperature And Pressure" i
5.1.4 12003-C,
" Reactor Startup" 1
I 5.1.5
- 13003,
" Reactor coolant Pump Operation" 5.1.6
- 13005,
" Reactor Coolant System' Draining" l
5.1.7
- 13006,
" Chemical And Volume Control System Startup And Normal Operation" 4
l 5.1.8
- 13009, "CVCS Reactor Makeup Control System" l
5.1.10 13010
" Boron Thermal Regeneration System" l
5.1.11 13011
" Residual Heat Removal System" 5.1.12
- 13120,
" Containment Building Cooling Systems' 5.1.13
- 13125,
" Containment Purge System" 5.1.14
- 13601,
" Steam Generator And Main Steam System i
Operation" 5.1.15
- 13605,
" Steam Generator Blowdown Processing i
System" 5.1.16
- 13610,
" Auxiliary Feedwater System" 5.1.17 13615
" Condensate And Feedwater Systems" 5.1.18 -
- 13616,
" Condensate Filter Domineralizer System" 5.1.19 13617 "Feedwater Heater Extraction, Vent And Drain System" 5.1.20
- 13620,
" Condenser Air Ejection System" 5.1.21
- 13724, "C'irculating Water System" i-e meses V
6
' aos n2
}*
pacesouas no.
navision VEGF 12006-L 10 40 of 42 i.
3 5.1.22
- 13760,
" Auxiliary Steam Boiler System" I
5.1.23
- 13761,
" Auxiliary Steam System" l
5.1.24
.13800,
" Main Turbine operation" 1
5.1.25 13810
" Generator Gas System" 1
l
" Turbine Steam Seal System" l
5.1.26
- 13825, 5.1.27
- 14000,
" Operations Shift and Daily Surveillance Logs" 4
5.1.28
- 14005,
" Shutdown Margir. Calculations" j
1 1
5.1.29
- 14748, "AFW Che::.
jve Cold Shutdown Inservice i
Test" 1
5.1.30
- 14915, "Special Conaitions Surveillance Logs" 5.1.31
- 24695, "N.I. System Source Range Channel Calibeation" i
5.1.32
- 24696, "N.I. System Source Range Channel
~
Calibration" 4
END 'OF PROCEDURE TEXT i
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RCS TBDERANES ( )
FIGURE 1
--RCS PRESSURE TEMPERATURE LIMITS 4.=
1 S
I I
+,
i haue no.
woocsouna mo.
navisscw VEGP 12006 10 42 of 42 c
I I
Sheet 1 of 1 i*
UNIT NO.
DATE
/
/
RCS/PRZR TEMPERATURE AND PRESSURE l
DATA SHEET I I
2Lovese Channel of TI-04138 i
TI-04235 TI-04335 PI-438LR or TI-04435 TI-0454 PI-405WR PRZR/RCS TIME RCS TEMP PRZR TEMP PRZR PRESS DELTA T t
i i
I i
i L
i 1
1 4
i 2
4 1
Completed 1
signature Date/ Time
)
Reviewed signature Date/ Time
' Il 0 nr ]*
' l2'k ' O/D G v 0 $ctl"<l b
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7(P I?Ccb-c Ic - 99 ~)
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i I
ELV- 00128 1
08900 j
December 29, 1988 i
U. S. Nuclear Regulatory Commission ATTN: Document Lontrol Desk l
. Washington, D. C.
20555 PLANT V0GTLE - UNITS 1, and 2
[
NRC D0CKET 50-424, 50-425 OPERATING LICENSE NPF-68, CONSTRUCTION PERMIT CPPR-109 1-FSAR CHAPTER 13 DESCRIPTION Gentlemen:
During the NRC visit at our Birmingham offices on December 19-21, 1988, you discussed a concern about potential differences between the FSAR Chapter
[
13 description of our corporate responsibilities and that which we verbally described to you at the meeting. We want to assure you that the information 1
i conveyed to you at the meeting is the way we are operating and the way we plan to operate in the future. That is, the Nuclear Support Departments in the corporate office are orpanized as a staff function to support the plant operation and not as a ine function to direct the operation of the plant.
However, as shown on FSAR Figures 13.1.1-2 and 13.1.1-3, the Executive Vice l
President, the Senior Vice President-Nuclear Operations and the Vice President-Nuclear, do provide lihe management direction for the operation of
-the Plant.
i.
As you are aware, the application to form the Southern Nuclear Operating Company (50N0PC0) has been submitted to the Security Exchange Consission (SEC) for approval. Once this application has been approved and implemented, we l
will be submittinfl an appropriate application to the NRC to amend the licenses for the Vogtle un'ts. At tiis time, we will thoroughly review and revise Chapter 13 of the FSAR as appropriate, to resolve any ambiguities that may
. exist.
[
Should you have any questions concerning the above, please inquire.
Sincerely.
l sJ. de r-s W. G. Hairston, III JA8/ijb c: Sse next page if h f/
L J
4 D 0 LO&O 88I $ f f
1 GeorgiaPower A U. S. Nuclear Regulatory Commission ELY-00128 December 29,'1988 Page Two 4
c: Georgia Power Company Mr. P. D. Rice Mr. C. K. McCoy Mr. G. Bockhold, Jr.
Mr. J. E. Swartzwelder GO-NORMS Yogtle-NORMS U. S. Nuclear Regulatory Conssission Mr. M. L. Ernst. Acting Regional Administrator 4
Mr. J. B. Hopkins, Licensing Project Manager, NRR (2 copies)
Mr. J. F. Rogge, Senior Resident Inspector-Operations, Vogtle d
I 4,*
. nnene w gi y m
m__ _._.
IllE p
I'lil'T IH b
ELV- 00109 X7GJ17-V110 0869D December 29, 1988 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D. C.
20555 PLANT V0GTLE - UNITS 1, and 2 NRC DOCKET 50-424, 50-425 l
OPERATING LICENSE NPF-68, CONSTRUCTION PERMIT CPPR-109 RESPONSE TO GENERIC LETTER 88-17 Gentlemen:
In accordance with 10 CFR 50.54(f), Georgia Power Company hereby submits the enclosed response to the recommended expeditious actions of Generic Letter 88-17 related to loss of residual heat removal while operating with a reduced reactor coolant. system inventory.
This response applies to both Units 1 and j
2, even though unit specific details may refer to Unit 1.
With regard to Unit v
1, the commitments contained in the enclosed res)onse will be implemented prior to the next planned entry into a reduced p"entory condition.
With regard to Unit 2, implementation will be achieved p.1or to the next planned entry into a reduced inventory condition after initial criticality, since the requirements of this Generic Letter are only applicable with irradiated fuel in the reactor vessel.
The responses provided are based upon current or proposed practices and may be changed in the future if appropriate.
j Mr. W. G.
Hairston, III states that he is a Senior Vice President of Georgia Power Company and is authorized to execute this oath on behalf of Georgia Power Company and that, to the best of his knowledge and belief, the facts set forth in this letter and enclosures are true.
GEORGIA POWER COMPANY l
M.. b I
By:
W. G. Hairston, III 1
Sworn to and subscribed before me this.29th day of December, 1988.
h My coenmlulen h-fres FMember 24,1 pet I
i DoppPublic gb
- /
i
$?OOdmK f)y
4 i,
j fM ENCLOSURE GEORGIA POWER COMPANY RESPONSE TO NRC GENERIC iETTER 88-17 RECOMMENDED EXPEDITIOUS ACTIONS t
1i i
The following discussion of Georgia Power Company's (GPC) plans for addressing i
the recommendations of Generic Letter 88-17 at Plant Vogtle (VEGP) is provided pursuant to 10 CFR 50.54(f):
l 1.
NRC RECOMMENDATION.
Discuss the Diablo Canyon event, related events, lessons learned, and implications with appropriate plant personnel. Provide training shortly before entering a reduced inventory condition.
l
- GPC RESPONSE The loss of. decay heat removal capability and associated potential consequences are. topics addressed in the initial and requalification training of licensed operators at VEGP. The Residual Heat Removal System t
(RHRS) lesson plan (LO-LP-12101-13-C) and the associated informational hand-out.(LO-H0-12101-003-C-002) discuss several concerns and industry events related to reduced inventory conditions.
y Included in the lesson plan and handout are discussions of the following:
- ~
o Related industry events; o
Recovery from a loss of RHR; i
Precautions and limitations associated with mid-loop ope'.ations; o
o Necessity of accurate, reliable vessel water level indication; and Vortex formation in the decay heat removal system.
o Operations Procedure 10000-C, " Conduct of Operations", addresses infrequent and unusual plant evolutions (e.g., mid-loop operations). The l
Shift Supervisor is required by this procedure to brief the individuals to i.
be involved in these evolutions.
Included in these briefings are 1
explanations of procedures, slans, and safety precautions involved in the evolution.- The details of tie briefings will depend on the complexity of the planned evolution.
The requirements of Operations Procedure 10000-C in conjunction with the
. licensed opepattor training, provides an adequate awareness on the part of
. personnel involved in mid-loop operations. Therefore, GPC believes that this recommended expeditious action has been appropriately addressed, and j
- no further action is planned.
- 2. D C RECOPME40ATION i
I ement pro dures and adai strative cont is that r asonabl h sure i
that ontaineen osure will achieved pri to the t at hi A a
- m
(
d y
+ -
% w w--)w
.T-
,--r
ii*
/
F
. Response to NRC Generic Letter 88-17
- 4
. Recommended Expeditious Actions l
Page 2 i
i 2.
_NRC RECOMMENDATION 1
Implement procedures and administrative controls that reasonably assure that containment closure will be achieved prior to the time at which a core uncovery could result from a loss of Residual Heat Removal (RHR) coupled. with an inability to initiate alternate cooling or addition of water -to the Reactor Coolant System (RCS) inventory.
Containment closure procedures should include consideration of potential steam and radioactive material release from the RCS should closure activities extend into the
-time boiling takes place within the RCS.
These procedures and i
administrative controls should be active and in use:
(a) prior to entering a reduced RCS inventory condition for Nuclear Steam Supply Systems (NSSSs) supplied by Combustion Engineering or 2
Westinghouse, and (b) prior to entering an RCS condition wherein the water level is lower than four inches below the top of the flow area of the hot legs at the junction.of the hot legs to the Reactor Vessel (RV) for NSSSs supplied by Babcock and Wilcox, W
and should apply whenever operating in those conditions.
If such procedures -and administrative controls are not operational, then either do not enter the appifcable condition or maintain a closed containment.
.GPC RESPONSE L
The capability to close containment within the required time in the event of a loss of RHR while in a reduced inventory condition will be ensured by
{
the following measures:
J 1.
The Shift Supervisor maintains cognitive control over the opening and closing of the containment equipment hatch via provisions of Maintenance Procedure 27505-C,
" Opening and Closing Containment Equipment Hatch";
2.
' Operations Procedure 12006-C, " Unit Cooldown to Cold Shutdown", (the controlling procedure for operations in the reduced inventory i c,._
conditi d will lbe revised to require that all containment netrations which have been opened by manual me will be tracked y an Information Limiting Condition for Operat jffyre 3.
Operations Procedure 12006-C will also be revised to incorporate a 4
i.
requirement to ensure that the containment. equipment hatch can be
- closed within ~ the applicable time requirements of Generic Letter 88-17, or ensure the hatch is: closed 4
to three feet below the' vessel flange; prior to reducing RV water level 4
. - ~
" b Response to NRC Generic Letter 88-17 Recommended Expeditious Actions Page 3 4.
In the event of a loss of RHR, Abnormal Operating Procedure 18019-C,
" Loss of RHR", will instruct the operators to initiate containment closure.
This procedure will be revised to require that all 4
non-essential personnel leave the containment and that all available containment cooling fans be started to help mitigate the effects of a loss of RHR~on the containment environment; j
5.
The site Emergency Plan will'be implemented in the event of a loss of RHR under the subject conditions.
This places the Emergency Director
~
.j
~ in charge of personnel engaged in containment closure, including.
i health physics personnel who would be responsible for radiation j
control and monitoring in the containment structure..
GPC believes that this recommendation will be appropriately addressed
[
when the procedures referenced above are revised.
l 3.
NRC RECOP91ENDATION Provide at least two independent, continuous temperature indications that t
are representative of the core exit conditions whenever the RCS is in a mid-loop condition and the reactor vessel head is located on top of the reactor vessel.
Temperature indications should be periodically checked and recorded by an operator or automatically and continuously monitored and alarmed.
Temperature monitoring should be performed either:
(a) by an operator in the control room (CR), or (b) from a location outside of the containment butiding with provision 4
for providing inmediate temperature values to an operator in the CR L
if significant changes occur.
Observations should be recorded at an interval no greater than 15 minutes during normal conditions.
CPC RESPONSE 1
Operations Procedures presently require at least two core exit thermocouples.to. be operable at all times during reduced inventory conditions Wthtthe ROheaddn;plade!
These procedures will be revised to require either:'-
1 I"
~1..
~
TemperMe will be monitored and recorded by an operator in the j.
control room at intervals no greater than 15 minutes, or
.2.
Temperature will be continuousl monitored and alarmed via the Emergency Response Facility (ERF) ycomputer in the control room.
I.
6
...m
~
m
.e
ig.
1 Response to NRC Generic Letter 88-17
!b Recommended Expeditious Actions Page 4:
j i
L If the_latter method is used, the operations procedures will require 1
notification of Instrumentation and Control personnel to revise the
[
computer, alarm setpoint to e conservative value above the expected RCS t
temperature.
i-~
GPC believes that this recommendation will be appropriately addressed when j
.the, procedures referenced above are revised.
1:
4.
NRC RECOMMENDATION i
{
Provide at least L two independent, continuous RCS water level. indications l
whenever the RCS is in a reduced inventory condition. Water level
}.
indications should be. periodically checked and recorded by an operator or automatically _ and continuously monitored and alarmed.
Water level 4
monitoring should be capable of being performed either:
j' (a) by an operator in the CR, or l
(b) ' from. a location other than the CR with provision for providing imediate water level values to an operator in the CR if significant changes occur.
Observations should be recorded at an interval no
_ greater than 15 minutes during normal conditions.
-V l~
GPC RESPONSE l
RCS' water level is monitored via temporary level instrumentation whenever the RCS in in a reduced inventory condition. Operations procedures include i-instructions to notify Instrumentation and Control personnel to install j
temporary level instruments prior to draining the RCS.
Instrumentation and Control Procedure - 23985-1, "RCS Temporary Water Level System",
[
provides instructions for installation of two independent channels of level indication using temporary transmitters and existing level instrumentation in the control room.
Level is measured directly from the hot leg between the RVLIS upper range lower tap and the pressurizer steam space -to minimize thermodynamic and pressure errors.
One channel provides wide range ~1evel indication-from approximately one foot below mid-loop to
-the. vessel flange.
The other channel provides narrow range level 1
indication from approximately one foot -below mid-loop to the top of the hot leg.
Level is continuously monitored and. alarmed in the control E c--
room.
A loCWye1. alarm ~ 1s set at three-inches above the center of the hot '. leg.
i In addition to = the temporary level transmitters, a tygor. tube is installed per Procedure 54890-1, " Installation and Removal Instructions-For The RCS t-Water. Level Tube".: The tygon tube is used as a backup to be continuously monitored -when operating below 175 pressurizer level, if either control room indication is lost or while reducing RCS level.
, - i-c GPC believes ' that' this recommendation is appropriately addressed, and no further action is planned.
k
-.. - -. - ~.
i j=
j'I Response to NRC Generic Letter 88-17
-k Recommended Expeditious Actions i
^Page 5 4
1-l
- 5.. MtC RECOMMENDATION j
Implement procedures and administrative controls that ' generally avoid j
operations that deliberately or knowingly lead to perturbations to the RCS and/or systems that are necessary to maintain the RCS in a stable and controlled condition while the RCS is in a reduced inventory condition.If I
operations ' that could perturb the RCS or systems supporting the RCS must be conducted while in a reduced inventory condition, then additional measures should be.taken to assure that the RCS will remain in a stable and controlled condition. Such additional measures include both prevention of a loss of RHR and enhanced monitoring requirements to ensure i
[
Ltimely response to a loss of RHR should such a loss occur.
s j
GPC RESPONSE VEGP has procedures in place that require authorization from. the Unit Shif t Supervisor prior to performing any work.
Operations procedures include precautions.to scrutinize. and limit work activities that have the potential for. reducing RCS inventory while in a reduced inventory condition.
These procedures will be revised to ensure that any work that t
may impact RHR capability while in a reduced inventory condition be
{
closely scrutinized.
Work will not be allowed to be performed unless V
adequate measures exist (such as enhanced monitoring of critical parameters and precautions and limitations) to prevent a loss of RHR.
i GPC believes that this recommendation will be appropriately addressed when L
the procedures referenced above are revised.
i 6.
NRC RECOMENDATION f
. Provide at least two available or operable means of adding inventory to the RCS that are in addition to pumps that are a part of the normal RHR i
systems.
These should include at least one high pressure injection pump.
The water addition rate capable of being provided by each of the means should be at least sufficient to keep the core covered.
Procedures for 4.
use of ' these systems during loss of RHR events should be provided.
The path of water addition must be specified-to assure the flow does not
[
bypass the reactor vessel before exiting any opening in the RCS.
GPC RESPONSE ~
~
i
-VEGP will maintain two available means of adding inventory to the RCS during. operation in a reduced inventory condition. The water addition rate will be at least sufficient to keep the core covered in the event of a
' loss!of RHR.
,y 6
y
-v-
,-1
f J
-[_'
Response to NRC Generic Letter 88-17 Recommended Expeditious Actions Page 6 The Technical Specifications require that a charging pump and an operable flow path to the RCS be maintained while in Modes 5 and 6.
Maintaining.
the charging pump operable. meets the requirement of Generic Letter 88-17
- for a high
>ressure injection pump for inventory addition.
Operations
~
procedures w'11 also-specify that a charging flow path to a closed cold leg be used in the event of a loss of RHR to prevent flow from bypassing the core.
In addition, a Safety Injection Pump and a hot leg injection path will be available by either revising the appropriate procedure or issuance of a Standing Order.
This will be done..to ensure the protection of the health and safety-of the Epublic nunden the provisions of 10.CFR 50.54(x).-
(Current Technical Specifications require that all Safety Injection Pumps be inoperable in Modes 4, 5 and 6 with the RV head on).
GPC believes that this recommendation will be appropriately addressed when the procedures referenced above are revised.
7.
IstC RECOMMENDATION Implement procedures and administrative controls that reasonably assure that all hot legs are not blocked simultaneously by nozzle dams unless a vent path is.provided that is large enough to prevent pressurization of the upper plenum of the RV.
GPC RESPONSE VEGP procedures will be revised to prevent blockage of the hot legs without an adequate vent path.
Maintenance procedures will be revised to i
include a prerequisite that a vent path for the hot legs be provided prior to the installation of the hot leg nozzle dams.
The cold leg nozzle dans will be installed first and removed last.
i i-Operations Procedures will be revised to ensure that a vent path is provided for the RV upper plenum if the hot leg nozzle dass are installed i.
i or a cold leg opening is to be established.
The operations procedures will define the vent path as one of the following:
1.Rega1Lofthepressurizermanway;or
'2. Removal of the steam generator manway on a hot-leg that will not be dammed; or 1-..
- 3. Removal of three pressurizer code safety valves.
_ GPC believes that this _ recommendation will be appropriately addressed when the procedures referenced above are revised.,
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Response to NRC Generic Letter 88-17 A
Reconnended Expeditious Actions Page 7 8.
NRC RECOMMENDATION Implement procedures and ad.r.friistrative controls that reasonably assure that all hot legs are not blocked simultaneously by closed stop valves
]
unless a
vent path.is provided that is large enough to prevent pressurization of the RV upper plenum or unless the RCS configuration prevents RV water loss if RV pressurizatTon should ' occur.
Closing cold legs by nozzle dans does not meet this condition.
GPC RESPONSE VEGP is not equipped with RCS loop stop - va lves, therefore, this reconnendation is not applicable.
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UNITED STATE 9
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NUCLEAR REGULATORY COMMISSION 8
WASHINGTON. D. C. 20666 NRC rec"'
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January 27, 1989 Si~~
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Mr. W. G. Hairston, III Senior Vice President -
Nuclear Operations Georgia Power Company P.O. Box 1295 Birmingham, Alabama 35201
Dear Mr. Hairston:
SUBJECT:
COMMENTS ON THE GEORGIA POWER COMPANY RESPONSE TOCEIiiERI O (1FTT ER 88-17]FOR THE V0GTLE PLANT, UNITS 1 AND 2 FOR EXPEDITIOUS ACTIONS FOR LOSS OF DECAY HEAT REMOVAL (TAC N05. 69789 AND 69790)
The NRC staff has reviewed your response to Generic Letter 88-17. We find that it generally meets the intentions of the generic letter with respect te expeditious actions and is adequate for plant operation.
'O The most significant contributor to risk reduction of the eight generic letter reconsnendations is the capabi11ty to close containment. Your response appears to be incomplete in the following respects:
1.
Tracking of containment penetrations references only those that have been opened by " manus 1 means." fund //h tW/<#' n * '"" ><
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2.
You specifically address closure of the equimnt hatch via Operations Procedure 12006-C which ensures "that the containment equipment hatch can be closed." Abnormal Operating Procedure 18019-C "will instruct the operators to initiate containment closure." We find no reference to actual completion of containment closure within allowable times, particularly with respect to penetrations other than the equipment-hatch.
1 Ant inr me40 4 m J r.a f wp t c o 3.
You identify that "all available containment cooling fans be started to help mitigate the effects of a loss of RHR on the containment You do not identify..what. reasonable. assurance is available environment."De available nor do you address whether you have that fans wi investigated the feasibility of continued work within containment once 5
boiling initiates within the reactor vessel and creates a steam enyironmmt within the containment.
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V' W. G. Hairston, 111 January 27, 1989 N
In regards to the other expeditious items, the program identified in your response has the capability to adequately address the concerns expressed in the generic letter.
However, your responses are brief and, therefore, do not allow us to fully understand your action taken in response to GL 88-17.
You may wish to consider several observations in order to assure yourselves that the actions are adequately addressed:
1.
You reference the commitments as implemented prior to the next planned i
entry. tie assume your meaning is for any entry into a reduced inventory 1
condition that is deliberate on the part of the operators. Hence, an
'4 entry for the purpose of repairing an unanticipated reactor coolant pump f
d fpe seal failure would be a planned entry. An entry due to a loss of coolant y
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accident would be unplanned. Any other meaning will not meet the intent
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of the generic letter.
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You also reserve the right to make changes "in the future if appropriate."
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/ l The intent of the generic letter is to allow changes under the guidance of M
the progransned enhancement reconsnendations and subject to your 50.59 review, as applicable.
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The lesson plan description did not identify the need for instrumentation
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other than level indication. Temperature and the ability to monitor RHR b
i behavior are also important.
i 4 The lesson plan description did not identify such vortex detail as symptoms and suitable operator response to prevent loss of RHR.
(- 5.
1' The lesson plan description is stated to provide "an adequate awareness on the part of sersonnel involved in mid-loop operations." Historical experience s10ws many RHR losses caused by apparently trained personnel -
of ten by maintenance and test personnel. Your program should be designed to avoid such difficulties.
- 6. pYfu indicate removal of a pressurizer manway, steam generator manway, or 4
three pressurizer code safety valves as means to provide RCS venting.
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,p' We note that relatively lar e hot side openings in the RCS such as a P
pressurizer manway, can sti 1 lead to a pressure of several psi due to the large steam flow and the combination of flow restrictions in the surge line - lower pressurizer hardware - manway opening.
Calculations should be performed to verify the effectiveness of the opening.
There is no need to respond to the above at this time.
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W. G. Hairston, III January 27, 1989 L
As you are aware, the expeditious actions you have briefly described are an interim measure to achieve an immediate reduction in risk associated with reduced inventory operation, and these will be supplemented and in some cases replaced by )rogrammed enhancements. While your response is adequate, we intend to audit bot 1 your expeditious actions and your programmed enhancement program.
The areas where we do not fully understand your responses as indicated above ray be covered in the audit of expeditious actions.
Sincerely, 3 b, a'
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, con B. Hopkin, Project lianager Project Directorate 11-3 Division of Reactor Projects - I/II' Office of Nuclear Reactor Regulation cc: See next page i
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Fu F29 '89 15:27 ID:50e rPCO-UOGTLE TEL 10:1-205-8??-7885 S1378 FOI i
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. GENERIC LETTER 88-17 LOSS OF DECAY HEAT REMOVAL 10PIC9 OF ANALY$EEE 1
o TIME REQUIREO TO INITIATE BOILING IN Rx VESSEL 1
o TIME REQUIRED To UNCOVER CORE 1
o INFLUENCE OF STEAM GENERATOR NOZZLE DAMS o CALCS, TO SUPPORT HOT SIDE OPENINGS IN RCS ARE 1.2 SUFFICIENT FOR VENTING PURPOSES 1.3 o FORCED & GRAVITY MAKE-UP TO RCS o STEAM GENERATORS FOR ALTERNATE COOLING / EFFECTS 1.4 1
OF. WATER IN S.G.
1 o FEASIBILITY OF CONTINUED WORK INSIDE CONTAINMENT ONCE BOILING INITIATES WITHIN TME Rx VESSEL &
2 CREATES A $ TEAM ENVIRONMENT WITHIN CONTAINMENT o
ADDRESS OPERATUR CONCERNS WHILE PERFORMING DRAIN DOWN fie - steam generator curoling. accurate level indication. and rate of drain down while differential pressures exists b/w Rx vessel steam generators:
and oressurizer) notes:
1.
REF. G.L.
88-17 SEC. 3.4.2 ANALYSES--REVIEW WCAP-11916 AS WELL AS WESTINGHOUSE'S FINAL i
ANALY3ES FOR THE ABNORMAL OPERATING PROCEDURE GUIDANCE--CONTACTS: GREG LEE (GPC)/ RICK AUSTIN (WESTINGHOUSE)/ BRIAN WHITLEY(FARLEY SONOPCO FROJECT) o-2.
SEE MRC COMhENTS ON GPC'S'RESPCNSE TO G.L.
88-17 EXPEDITIOUS ACTION $ DATED JAN. 27.1989 3.
SEE GPC 90 DAY RESPONSE--WE-MADE COMMITMdNT 4.
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ELV- 00186 i
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February.2, 1989 U. S. Nuclear Regulatory Commission
~ ATTN: Document Control Desk Washington, D.'C.
20555 PLANT V0GTLE - UNITS 1, and 2 NRC DOCKET 50-424, 50-425 OPERATING LICENSE NPF-68, CONSTRUCTION PERMIT CPPR-109 RESPONSE'TO GENERIC LETTER 88-17 Gentlemen:
. In accordance with 10 CFR 50.54(f), Georgia Power Company hereby submits the. enclosed response to the recommended programmed enhancements of Generic Letter 88-17 related to loss of residual heat removal while operating in a y
reduced' inventory condition. This response applies to both Units 1 and 2, even though unit specific details may refer to Unit 1.
Georgia Power Com)any responded to the recommended expeditious actions of Generic Letter 88-17
)y letter dated December 29, 1988 Georgia Power Company expects to implement all hardware changes resulting from the programmed enhancements prior to resuming critical plant operations following the second Unit 1 and first Unit 2 refueling outages. Enhancements that do not involve hardware changes are scheduled to be implemented by May 3, i
'1990.-
j i
Evaluation of' hardware changes for level instrumentation and residual heat i
removal system performance indication has not been completed.
In that the i
. evaluation is not complete, Georgia Power Company cannot be more specific than the enclosed response. Georgia Power Company will submit a description of these hardware changes within approximately two months following completion of the evaluations, which is currently projected for October 1, 1989.
The enclosed responses are based upon current or proposed practices and i
- may.be changed in the future, if appropriate.
Information related to this
. issue will I)e evetlable onsite for NRC review.
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If.there are any questions concerning this_ letter, please advise.
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Georgia Power V
.U. S. Nuclear Regulatory Commission
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ELY-00186
.Page 1wo Mr. W. G..Hairston, III states that he is a Senior Vice President of Georgia Power Company and is authorized to execute this oath on behalf of Georgia Power Company and that, to the best of his knowledge and belief, the i
facts set forth in this letter and enclosures are true.
GEORGIA POWER COMPANY By:'_W
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i W. G. Hairston, III Sworn to and subscribed before me this 2nd day of February, 1989.
S ti n. b - 1 1 $ Y $ $
M#tary Public Att MutKt, te,. 3, ;
e c: Georgia Power Company Mr. P. D. Rice Mr. C. K. McCoy Mr. G. Bockhold, Jr.
GONORMS U. S. Nuclear Regulatory Commission-Mr. M. L. Ernst, Acting Regional Administrator Mr. J. B. Hopkins, Licensing Project Manager, NRR (2 copies)
Mr. J. F. Rogge, Senior. Resident Inspector-Operations, Vogtle j
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l ENCLOSURE GEORGIA POWER COMPANY RESPONSE TO NRC GENERIC LETTER 88-17 PROGRAMED ENHANCEMENTS The following discussion of Georgia Power Company's (GPC) plans for addressing the programmed enhancements of Generic Letter 88-17 at Plant Vogtle (VEGP) is provided pursuant to 10 CFR 50.54(f):
1.
NRC RECOMMENDATION Provide reliable indication of parameters that describe the state of the reactor coolant system (RCS) and the performance of systems normally used to cool the RCS for both normal and accident conditions. At a minimum, provide the following in the control room:
(a) Two independent RCS level indications.
(b) At least two independent temperature measurements representative of the core exit whenever the reactor vessel (RV) head is located on top of the RV.
(We suggest that temperature indicatfons be provided at all times.)
(c) The capability of continuously monitoring residual heat removal (RHR)
+
system performance whenever an RHR system is being used for cooling j
i the RCS.
(d) Visible and audible indications of abnormal conditions in temperature, level, and RHR system performance.
~
GPC RESPONSE (a) As stated in our December 29, 1988 submittal, RCS water level is monitored via temporary level instrumentation whenever the RCS is in a reduced inventory condition. Operations procedures include instructions to notify Instrumentation and Control personnel to install temporary level instruments prior to draining the RCS.
Instrumentation and Control Procedure 23985-1, "RCS Temporary Water Level System", provides instructions for installation of two independent channels of level indication using temporary transmitters and existing level instrumentation in the control room. Level is measured directly from the hot leg between the RVLIS upper range lower 4apandthepressurizertominimizethermodynamicandpressure errors.. One channel provides wide range level indication from approximately one foot below mid-loop to the vessel flange. The other channel provides narrow range level indication from approximately one foot below mid-loop to the top of the hot leg.
Level is continuously monitored and alarmed in the control room.
A low level alarm is set at three inches above the center of the hot leg.
GPC is presently evaluating a design change which will provide for permanent installation of the leve transmitters. We expect to have this evaluation completed by October 1, 1989.
Response to NRC Generic Letter 88-17 ELV-00186 Page Two The design development will include a review of the instrumentation design and an error analysis. GPC will also perform a quality control and follow-us review of the installation and review j
maintenance and cali) ration practices.
(b) Operations Procedures presently require at least two core exit i
j thermocouples to be operable at all times during reduced inventory conditions with the RV head in place. However, during head i
installation, before the thermocouples can be connected, water level will be reduced to approximately four feet below the RV flange as recommended by Westinghouse to prevent 0-ring seating area damage.
After head installation, water level will be raised so that the RCS
]
is no longer in a reduced inventory condition.
These procedures will
~
be revised to require either:
- Temperature will be monitored and recorded by an operator in the
]
control room at intervals no greater than 15 minutes, or 1
i
- Temperature will be continuously monitored and alarmed via the j
Emergency Response Facility (ERF) computer in the control room.
These two core exit thermocouples will provide continuous,
,v independent, and representative indication of the core temperature.
4 I
(c)
An engineering study will be made to determine the specific 1
parameters that will provide timely, reliable indication of the onset of degraded RHR pump performance. The study will include consideration of the recommendations of Generic Letter 88-17 such as indication of pump motor current, noise monitoring, suction pressure j
indication, and a possible correlation of parameters. We expect to i
complete this study by October 1, 1989. The results of this study will be implemented according to the schedule discussed in the cover letter to this transmittal.
1 (d) As discussed above,_RCS level is continuously monitored and ala'rmed in-the control room during operation in a reduced inventory condition. Temperature will either be checked and recorded by an operator in the control room at intervals no greater than 15 minutes, or continuously monitored and alarmed via the ERF computer in the control room. The engineering study discussed in item (c) above, i
will include consideration of visible and audible indication of RHR system performance.
- 2. NRC RECOMMENDATION Develop and implement procedures that cover reduced inventory operation and that provide an adequate basis for entry into a reduced inventory condition.
These include:
(a) Procedures that cover normal operation of the NSSS, the containment,
-and supporting systems under conditions for which cooling would 1
normally. be provided by the RHR system.
7-
- j.
b' Response to NRC Generic Letter 88-17 ELV-00186 b-i Page Three (b) Procedures that cover emergency, abnormal, off-normal, or the i
equivalent operation of the NSSS, the containment, and supporting systems if an off-normal condition occurs while operating under j
conditions for which cooling would normally be provided by the RHR system.
i (c) Administrative controls that support and supplement the procedures in
}
items (a), (b), and all other actions identified in Generic Letter 88-17, as appropriate.
GPC RESPONSE (a) As stated in our December 29, 1988 submittal, the controlling procedure for operation in a reduced inventory condition is Operations Procedure 12006-C, " Unit Cooldoun to Cold Shutdown." This procedure contains precautions and limitations concerning operation in a reduced inventory condition and provides guidance for preparing the RCS for draining This guidance address temperature and level j
instrumentation. RHR pump performance, and the use of a safety
)
injection pump for inventory addition, if needed.
' Procedure 13005-1, " Reactor Coolant System Draining", provides gy instructions for draining the RCS. This procedure also contains precautions concerning the effects of RCS level on RHR system operability and instructions which should minimize the impact of l
draining on level indication.
Procedure 13011-1 " Residual Heat Removal System", provides the necessary instructions for operation of the RHR cystem including operation in a reduced inventory condition. The precautions of this procedure address the effect of RHR system flow on pung suction j:
during reduced inventory operation, j
(b)
In the event of a loss of RHR, Abnormal Operation Procedure 18019-C,
" Loss of RHR", will provide the necessary guidance to ensure core j
cooling and direct the operators to initiate containment closure.
The operator will initiate a manual containment isolation actuation to close all penetrations which can be remotel Any penetrations which have been opened manually (y closed.
i.e. those which cannot i
.be remotely actuated or which have been disabled in the open position) will be tracked by an Information Limiting Condition for Operation (LCO) so that action can be taken to close these penetnttons. Closure of the equipment hatch will be accomplished via Maintenance Procedure 27505-C, " Opening and Closing Containment Equipment Hatch".
(c)
In addition to the above, Administrative controls will also ensure that the following is available for recognizing and mitigating a loss of RHR event:
- Instrumentation,
- Equipment for inventory addition,
- Adequate hot leg vent path, and
- Safe work environment to complete containment closure.
t Response to Generic Letter 88-17 ELV-00186 b
Page Four GPC believes that, with the revisions to procedures discussed in our 1-December 29, 1988 submittal, VEGP procedures will reflect the best current j
practice with regard to operation in a reduced inventory condition.
However, any further guidance that results from Westinghouse Owners' Group i
activity on this topic will be_ reviewed and incorporated into procedures as appropriate.
- 3. NRC RECOMMENDATION j
(a) Assure that adequate operating, operable, and/or available equipment of high reliability is provided for cooling the RCS and for avoiding a loss of RCS cooling.
l (b) Maintain sufficient existing equipment in an operable or available status so as to mitigate loss of RHR or loss of RCS inventory, should i
they occur. This should include at least one high pressure injection l
pump and one other system. The water addition rate capable of being i
provided by each equipment item should be at least sufficient to keep the core covered.
I i
(c) Provide adequate equipment for personnel communications that involve activities related to the RCS or systems necessary to maintain the j (.
RCS in a stable and controlled condition.
i t
j GPC RESPONSE (a) The RHR system at VEGP is part of the Emergency Core Cooling System l
-(ECCS). This system is safety related and therefore highly reliable. Furthermore, the RHR autoclosure interlock function is defeated in Modes 5 and 6 which eliminates the associated potential j
for spurious closure of the RHR suction isolation valves.
I (b)
Inventory addition will be accomplished via a centrifugal charging i
i pump and a safety injection pump. Both of these pumps are part of the ECCS and are therefore highly reliable.
The flowrates available from these pumps will be more than sufficient to keep the core covered. Administrative controls will ensure that flow paths are available for these pumps and that flow will not bypass the core.
Furthermore, Procedure 18019-C provides for the use of the steam generators as an alternate means of cooling when appropriate.
)
i (c) Adequ_att equipment for personnel connunications during reduced invent 6ry operation presently exists at VEGP and is required by i
procedure,
- 4. NRC RECOMMENDATION Conduct analyses to supplement existing information and develop a basis for procedures, instrumentation installation and response, and equipment /NSSS interactions and response. The analyses should s
encompass thermodynamic and physical (configuration) states to which j
the hardware can be subjected and should provide sufficient depth that the' basis is developed.
Emphasis should be placed upon obtaining a complete understanding of NSSS behavior under non-power operation.
I
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Response to NRC Generic Letter 88-17 ELV-00186 Page Five l
GPC RESPONSE GPC, as a member of the Westinghouse Owners' Group, has reviewed WCAP-11916 and utilized the analysis and guidance provided therein as a basis for the hardware and procedural changes discussed in our December 29, 1988 submittal.
Further analysis is being performed by Westinghouse to validate the abnormal operating procedure guidance. When this analysis is complete and the procedural Juidance finalized, GPC will review the information for VEGP and make cianges as appropriate.
In addition, the design review discussed for RCS-level instrumentation will account for effects that may introduce level inaccuracies. Furthermore, special 2
pre-operational testing has been performed on Unit 2 which varied RCS 4
^
level and RHR system f ow to determine susceptibility to vortexing.
Finally, a plant specific analysis will be made to support inventory j
addition via gravity flow from the refueling water storage tank to the RCS.
l
- 5. NRC RECOMMENDATION Technical Specifications that restrict or limit the safety benefit of the actions identified in this letter should be identified and appropriate changes should be submitted, j
GPC RESPONSE GPC plans to pursue a change to the Technical Specifications which will allow the safety injection pumps to be available during operation in a reduced inventory condition without having to invoke 10 CRF 50.54X.
6.
NRC RECOP94ENDATION Item (5) of the expeditious actions should be reexamined and operations refined as necessary to reasonably minimize the likelihood of loss of RHR.
GPC RESPONSE As stated in our December 29, 1988 submittal, VEGP has procedures in place that require authorization from the Unit Shift Supervisor prior to performing any work. Operations procedures include precautions to scrutinire and limit work activities that have the potential for reducing RCS inventory while in a reduced inventory condition. These procedures will be revised to ensure that any work that may impact RHR capability w
while in-eweduced inventory condition be closely scrutinized. Work will not be allowed to be performed unless adequate measures exist (such.as enhanced monitoring of critical parameters and precautions and limitations) to prevent a loss of RHR.
GPC believes that the above measures in conjunction with the emphasis placed on mid-loop operations during licensed operator training and the other measures discussed in this letter and our December 29, 1988 letter are adequate.to minimize RCS perturbations during reduced _ inventory operation.
GUp a P(# CMirtan, c
si"::::;; n leieftfWT 404 526 3195 af : "
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Pos' O'l re Poe 1295 Bengham A!ataama 35201 Teiephone 205 86R 5581 November 30, 1989
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W. G. Hairston,111 Senior Vee Pres dent Nuclear Operabons l
ELV-01092 0127 Docket Nos. 50-424 50-425 U. S. Nuclear Regulatory Coimission ATTN: Document Control Desk Washington, D. C.
20555 Gentlemen:
i V0GTLE ELECTRIC GENERATING PLANT l
HARDWARE MODIFICATIONS PURSUANT TO GENERIC LETTER 88-17 By letters dated December 29, 1988-(ELV-00109) and February 2, 1989 (ELV-00186),
j Georgia Power Company (GPC) responded to Generic Letter 88-17 related to loss of j
residual heat removal while operating with a reduced reactor coolant system i
inventory. Our letter of February 2,1989 stated that an evaluation of hardware changes for level instrumentation and residual heat removal system performance indication was underway and that a description of these hardware changes would be submitted approximately two months after completion of the evaluation.
With regard to RCS level-instrumentation, GPC plans to install permanent mounts nr temporary level transmitters. The transmitters themselves will be installed prior to entry into a reduced inventory condition and removed upon ryihng the reduced inventory condition. The tygon tubing, which has been used as a backup to the two independent channels of level indication arovided by the transmitters j
discussed above, will be replaced by sight glasses witch will be permanently installed, but removed from service when the unit is not in reduced inventory operation.-
Residual heat removal (RHR) pump performance indication will be enhanced by providing indication and alarm of RHR pump motor current instability. This will be accomplished via the Safety Parameter Display System (SPDS) and the Emergency Response Facility-(ERF) computer. The Critical Safety Function Status Tree logic will be revised to include a link to RHR pump motor current during Modes 5 and 6.
If motor current instability is detected, an audible alarm will be generated by-thetERF computer. At the same time the Core Cooling critical safety function will-be illuminated on the SPDS display. The operator will refer to the Core Cooling function via the ERF computer and RHR pump motor L
current will-be indicated or trended.
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l U. $. Nuclear Regulatory-ELV-01092 Eggs Two i
GPC believes that these hardware changes, accompanied:by the other measures.
- described in our letters of December 29, 1988 and February 2, 1989 adequately address the potential.for loss of residual heat removal during operation with a reduced reactor coolant system inventory.
If there are any questions concerning this letter, please contact.this office..
Sincerely,
~
W. G. Hairston, III WGH.III/NJS/gm j
. xc:. Georaia Power Company Mr. C. K. McCoy Mr. G. Bockhold, Jr.
Mr. P. D.-Rushton Mr. R. M. Odom
' NORMS U. S. Nuclear Reaulatory Commission Mr. S. D. Ebneter, Regional Administrator Mr. J. B. Hopkins, Licensing Project Manager, NRR /
Mr. J. F. Rogge, Senior Resident Inspector, Vogtle 4
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