Text

Proposed Tech Specs for Extension of Instrumentation Surveillance Intervals & Allowed Outage Times
	ML20113H603
Person / Time
Site:	Grand Gulf
Issue date:	07/29/1992
From:	; ENTERGY OPERATIONS, INC.
To:	;
Shared Package
ML20113H602	List: ML20113H600; ML20113H603;
References
	NUDOCS 9208050078
	Download: ML20113H603 (70)
	v • d • e

. . .

Attachment 3 to GNRO-92/00099 Page.1 of 39

_l MARK-UP OF AFFECTED j TECHNICAL SPECIFICATION PAGES FOR PCOL - 92/03 1

(

9208050078 920729 "'

PDR- ADOCK 05000416 P PDR i

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~ Attachment 3:to GNRO-92/00099 Page 3 of 39

'. INSTRUMENT ATION --

iEND-0F CYCLE !!ECIRCULATION PUMP TRIP 5YSTEM INSTRUMENTATION

. LIMITING CONDIT!0N FOR- OPERATION 3.3.4.2 The end-of-cycle recirculation pump trip (EOC-RPT) systes

-instrumentation channels shown in Table 3.3.4.2-1 shall be OPERA 8LE with.their-trip setpoints set consistent with the values shown in the Trip setpoint column of Table 3.3.4.2-2 and-with the END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME as shown in Table 3.3.4.2-3.

APPLICA8ILITY: OPERATIONAL ~ CONDITION 1, when THERMAL POWER is greater than or Lequal to 4cz of RATED THERMAL POWER.

-ACTION:

a. With an end-of-cycle recirculation pump trip system instrumentation channel' trip setpoint less conservative than the value shown in the Allowable Yalues column of Table 3.3.4.2-2,' declare the channel inoperable until the channel is restored to OPERA 8LE status with-the channel setpoint adjusted consistent with the Trip Setpoint value.

b. With the number of OPERA 8LE channels one less than required by the Minimum OPERABLE Channels- per Trip System requirement for one or both trip systems, place the inoperable channel (s) in the-tripped condition

.within : = h:.

6,]

c. - With the number of CPERABLE channels two or more less than required by the Minimum OPERA 8LE Channels per Trip System requirement for one '

-trip system and:

4

~1.- -If_ the inoperable channels consist of one turbine control valve

. channel and one turbine stop velve channel, place both inoperable channels"in the tripped condition within ::: h: g g l

2. If the inoperable channels include two turbine control valve

channels -or two turbine stop valve channels, declare .the trip -

!systes; inoperable.

d. With one trip system inoperable, restore the inoperable trip system ,

to OPERABLE: status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or reduce THERMAL POWER to less than 405 of RATED THERMAL POWER within the next,5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

e. With both trip systems inoperable, restore at least 'one trip system

' to OPERABLE' status ~ within one hour or reduce THERMAL POWER to less-

- than 405-of RATED THERMAL POWER within the next 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

r-l'- _I

~ GRAND GULF-UNIT 1 3/4 3-41 Amendmenf do -

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E l Attachment 3 to.GNRO-92/00099 l Page 3 of 39 {

.;. I 1

-TABLE 3.3.4.2-1 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION MINIMUMOPERABLECHAN((gSPER TRIP FUNCTION TRIP SYSTEM

1. Turbine Stop Valve - Closure 2(b) 2 CD)

2. Turbine" Control Valve - Fast Closure (a) -A trip system may be placed in an inoperable status for up to## hours for required surveillance provided that the other trip system is OPERABLE.

(b) This function shall be automatically. bypassed when operating below the appropriate turbine first stage pressure setpoint of (1) < 26.9% of the value of turbine first-stage pressu're at valves wide open (VWO) steam flow when operating with rated feedwater temperature of greater than or equal to 420*F; or 1

-(2) < 22.5% of the value of turbine first-stage pressure at VWO ste m

~ Tiow when operating with rated feedwater. temperature between 370*F and 420*F.-

These' represent allowable setpoint values of turbine first-stage pressurer equivalent to THERMAL POWER less than-40% of RATED THERMAL POWER.

L i

l-t i Amendment No. 16,._,,

L GRAND GULF-UNIT 1 3/4 3-43

L:

z Attachment 3 to GNRO-92/00099 Pago'4 of.39

!NSTRUME' NTATION :

-TABLE 4.3.4.2.1 1 z .,

END-OF-CYCLE-RECIRCULATION PUMP TRIP SYSTEM 5URVEILLANCE REQUIREMENT 5 CHANNEL FUNCTIONAL CHANNEL TRIP FUNCTION . TEST CAllBRATION-1; Turbine Stop Valve - Closure M" R

- 2.. Turbine Control Valve - Fast Closure R

!ncluding Trip system logic testing. N

C alibrate trip units _ and logic at-least -once per h days.

i;

-GRAND GULF-UNIT 1 3/4 3-46 Am'ad M4+ Mo -

.s

' TABLE 3.3.5-l'.

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o .,.

@ REACTOR CORE ISOLA! ION COOLING SYSTEM ACTUATION IN5TRUMENTATION Q ' MINIMUM I

A OPERA 8LE CHANNELS *I' ACTION g

fuhCT10NAL UNITS 4 50

" - a. Reactor Vessel Water Level - Low low, Level 2 2 51

b. Reactor Vessel teater Level - Higih,- Level .8

~!

2 52

c. Condensate Storage Tank Water Level.- Low 2 52 .,

d. Suppression Peel Water Level - High 1 53

e. Manual Initiation -

.a S 4 (a) A channel may be placed'n'inthel an inoperable status for up to-f* hours for required surveillance without tripped condition provided at least one other OPERA 8tE channel in the placing the trip system same trip system is mealterlag that parameter. 25 tr

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.~ -.. _ . - - - ~ ~ - - - - - - - - ~ ~ ~ '"' ~ ^^^^~ ~ ~ ~ ~ ~ ~ ~ ~ ~

Attachment 3 to GNRO-92/00099 Page 6 of 39 9 lNSTRUMENTATION .

TABLE 3.3. 5-1 (Continued)

_ REACTOR CORE ISOLATION COOLING SYSTEM l

{ h q (-

l ACTUATION INSTRUMENTATION ACTION 50 - kWth th; n=t:r ;f ;MP'RE.:humh kwth;n ec;uired by the- '

didih10FCEACLt'Chennel; ,quir;;;nt, place the in;peraLie channel (s) er trip ;yst:: in the tri;;;d ;r4Hica i%f, on f.e , er_diciere th; RCIC ;y;t ; k;per:ble.

ACTION 51 -

With the number of OPERABLE channels less than required by the-minimum OPERABLE _ channels requiremnt, declare the RCIC system inoperable g g ,- gQ g i ACTION 52 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requirem nt, place at least one inoperable channel in the tripped condition within n 5;;r j or declare the RCIC system inoperable.

ACTION 53 - 2'l h.e s With the number of OPERABLE channels less than required by the Minimus OPERABLE Channels requirement, restore the inoperable channel to OPERABLE status within % hours or declare the RCIC system inoperable. l 24 GRAND GULF-UNIT 1 3/4 3-49 ANb -

Attachment 3 to GNRO-92/00099 Pago 7 of 39 INSERT TO PAGE 3/4 3-49 With the number of OPERABLE channels-less than required by the Minimum OPERABLE Channels requirement:

a. With one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the RCIC system inoperable.

b. With more than one channel inoperable, declare the RCIC system inoperable.

=

1 9

l 5 i i

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.:l E TA8tE.4.3.5.1 F o

8 REACTOR CORE ISOLATION COOLING SYSTEM .*CTUATION INSTR MENTATION SURVEILLANC CHANNEL .

& -CHANNEL F WCTIONAL2 CHANNEL-

' CHECK TEST CALIBRATION FUNCTIONAL UNITS.'

w

a. Reactor Vessel Water Level - R(*

Low Lew Leve1~2' S- 9f R

b. Reactor Vessel Water Level High. Level 8 5

f

c. Condensate Storage Tank. R Level - Lou 5 h*4t-

$ d. Suppression Pool Water Level - R High 5 @ y b) NA U e. Manual Initiation NA. _

-(a) Calibrate trip unit at least once pere days. l

-5>

.(b) Manual initiation switches shall be tested at least once per 18 months during shutdown.

All other $$

circuitry assectated with eenmal initiation shall receive a CHANNEL FUNCTIONAL TEST at least once o@

per ) r days as a part of circuitry required to be tested.for automatic system actuation, y ag lL

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Attachment 3 to GNRO-92/00099 Page 9 of 39

. INSTRUMENTATION-3/4.3.6 CONTROL R00 8 LOCK INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.6. The control rod block instrumentation channels shown in Table 3.3.6 1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.6-2.

APPLICABILITY: As shown in Table 3.3.6-1.

ACTION:

a. With a control rod block instrum ntation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.6-2, declare the channel inopertble until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value,

b. With the number of OPERABLE channels less than required by the Minti m OPEP.ABLE Channels per Trip, Function requirement, take the ACTION required by Table 3.3.6-1.

'SUPVEIlLANCE REQUIREMENTS ,

ach of the above required control rod block trip systems and co,A i s rumentation channels s6411 be demonstrated WELgOLC-by the performance of I da *" the CHANNEL CHECX, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations k'h3 $ and at he frequ i shown in Table 4.3.6-1.

4. s . c. 2 oC q. o. 4 ace na4 cqplTLe icale provisconsJ lo Lele Fva4toml

%y e c tJe.s4 C ces s io ,

sauelllasees -Coe Ne .D hrmebede Rage ino ~i J-or s a4 &aece 1%y tod4-ces S-o e e< dry kle &*,

off h ed le OPERM/oMAL 6 DMO /MCMS (as 3 fee.$eN ir mie 4.3.G- / hem OPM/W

( Con oi riod l i P " d 'd A " " "

parad wa.w 12 Loucs dh< sock ed7 -

l 1 GRAND GULF-UNIT 1 3/4 3-52 Q$e d A/o. _____

Attachment 3 to GNRO-92/00099 Page 10 of 39 INSERT TO PAGE 3/4 3~52

_A channel may be-placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition, provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.

o TABLE 3.3.6-1 g -:1 g CONTROL ROO BLOCK INSTRUMENTATION h MINIMLM APPLICABLE p OPERABLE CHANNELS- OPERATIONAL-j TRIP FUNCTION HRTRIPFUNCTION CONDITIONS ACTION.

" -1. ROD PATTERN CONTROL SYSTEM a.- Lew Power Setpoint 2 1, 2 60

b. High-Power.Setpoint 2 1# 60

2. APRM

a. Flow Biased Neutron Flux-Upscale 6 1 61

b. Inoperative 6 1, 2, 5 61

c. Downscale 6 1 61

d. Neutron Flux - Upscale, Startup 6 2, 5 61 3.

w SOURCE RANGE MONITORS

a. Detector not full ing) 4 yk W 2*, 61 g 2** aM S 62

b. Upscale (b) -4 Afc3 30, 2*# 61

'2** mR 5 62 2$

c. Inoperative I} 4 2* # 61 2"* 1 5 62

$k_

- :r -

d. Downscale(c) 4 / 2 h 61 2** 5 62 m et

4. ' INTERMEDIATE RANGE MONITORS uw

a. Detector not full in 6 2, 5 o 61

{s

b. Upscale

c. Inoperatig) 6 6

2, 5 -61 O

( d. Downscale 6 2,

2, 5

5 61 y

=

61 g

" w.

5. SCRAM DISCHARGE VOLUME N y Water Level-High a.

h

2 1, 2, 5* l h 6. REACTOR-COOLANT SYSTEM RECIRCULATION FLOW

a. Upscale w

3 1

% l

7. REACTOR MODE-SWITCH SHUTDOWN POSITION 2 3, 4 63

~

Attachment 3 to GNRO-92/00099 Page 13 of 39 '

3NSTRUMENTATION TABLE 3.3.6-1 (Continued)

CONTROL R00 BLOCK INSTRUMENTATION ACTION ACTION 60 -

Declare Specification the RPCS 3.1.4.2.inoperable and take the ACTION required by ACTION 61 -

With the number of OPERA 8LE Channels:

a. y One less than required by the Minisue OPERABLE Channels per Trip Function requirement, restore the inoperable channel -

to OPERA 8LE status within 7 days or place the inoperable channel in the tripped condition within the next hour, b.

Two or more less than required by the Minimum OPERABLE Channels per Trip Function requirement, place at least one inoperable channel in the tripped condition within one hour.

ACTION 62 -

With the nunber of OPERA 8LE channels less than required by the Minisun OPER) ALE Channels per Trip Function requirement, place the inoperable channel in the tripped condition within one hour.

ACTION 63 -

With the number of OPERA 8LE channels less than required by the Minimum OPERA 8tf Channels per Trip Function requirement, initiate a rod block.

_ NOTES With mors th&: one control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

OPERA Specification 8LE channels 3.9.2. must be associated with SRMs required OPERA 8tE per Vith THEfeAL. POWER greater than the 5.ev Power Setpoint.

M gg (a)

This function shall be automatically bypassed if detector count rate is

> 100 cps or the IRM channels are on range 3 or higher.

4Ag' 3*,(b)

This function shall be automatically bypassed when the associated IRM channels are on range 8 or higher.

(c) This function shall be automatically bypassed when the IRM channels are on range 3 or higher.

(d) This function shal e au omatically b pa ,j g e IRM channels are n nge 1.

.;q!; $ /)/ e rse v e r- N.t (th. & h ^C '0^ 'E b) f' /

gdClMfd N M des b ) N rov (C. y

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3/4[54 ~

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GRAND GULF-UNIT 1 '

Mendment No. 69 - l

Attachment 3 to GNRO-93/00099 Page 13 of 39

..i

INSERT.TO.PAGE 3/4 3 ,

ACTION _641- With the number of_ OPERABLE channels-less than- .

- required by the Minimum-OPERABLE Channels per Trip

_ Function requirement, place the inoperable channel --

in the. tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . '

4 l

l l

l f

y TABLE 3.3.7.1-1 (Continued)

$ ' RADIATION HONITORING INSTRUMENTATION h HININUM CHANNELS APPLICABLE ALARH/ TRIP MEASUREMENT INSTRUMENTATION OPERABLE CONDITIONS SETPOINT

] RANGE ACil0N E 10. Area Monitors

i a. fuel Handling Area

~ Monitors New fuel ~2

1) 1 (e) 12.5 mR/hr/NA 10 to 10 mR/hr 72 Storage Vault

2) Spent fuel 1 10

-2 3 (f) 12.5 mR/hr/NA to 10 mR/hr 72 Storage Pool u 3) Dryer Storage 1 (g) $2.5 mR/hr/NA 10~ to 103mR/hr 72 h Area

~2 o b. Control Room 1 At all times -<0.5 mR/hr/NA 10 to 10 3mR/hr 72 Radiation Monitor With RHR heat exchangers in operation. m>

When irradiated fuel is being handled in the primary or secondary containment.

Initial setpoint. Final Setpoint to be deteralaed during startup test program. Any required change to

$E 8

this setpoint shall be submitted to Commission within 90 days after test completion. Zg

1. With ADHR heat exchangers in operation. o (a) Trips system with 2 channels upscale-fli Hi Hi, er one channel upscale Hi Hi Hi and one channel downscale or SS 2 channels downscale. ua E' (b) Isolates containment /drywell purge penetrations. e,

@ (c) With irradiated fuel in spent fuel storage pool. o

& (d) Also isolates the Auxiliary Building and Fuel Handling Area Ventilation Systems.

3 (e) With fuel in the new fuel storage vault. a (f) With fuel in the spent fuel storage pool. $

(g) With fuel in the dryer storage area. 4 (h) Two upscale Hi Hi, one upscale Hi Hi and one downscale, or two downtcale signals from +

ime trip q

$ system actuate the trip system and initiate isolation of the associated isolation van o S

CO L ,

.s. - _.

-Attachment 3'to-GNRO-92/00099 Page 15 of 39 INSERT TO PAGE 3/4 3-60 A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

for required surveillance without placing the trip system in the tripped condition, provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.

Attachment 3 to GNRO-92/00099 Page 16 of 39

' INSTRUMENTATION TABLE 3.3.7.1-1 (Continued)

RADIATION MONITORING INSTRUMENTATION ACTION LACTION 70

- With the required monitor inoperable, ebtain and analyze at least one grab sample of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 71 [ DELETED]

ACTION 72- With the required monitor inoperable, perforn area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 73 -

a.

6h With one of the required monitors in a trip system inoperable, place the ' operable channel in the downscale tripped condition within a uvui; restore the inoperable channel to OPERABLE l status within 7 days, or, within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , initiate and maintain operation of at least one cientrol room emergen:y g filtration system in-the isclation mode of operation. \

b. With both of the required monitors in a trip system inoparable, initiate and maintain operation of at least one control room

. emergency filtration system in the isolation mode of operation within one hour.

ACTION 74

a. With one of the required monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condit:on I within = c (o =. g g ( g

b. With two of the. required monitors in a trip system inoperable, isolate tne containment and drywell purge and vent penetrations within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 75 -

c. With one of the required moniwrs in a trip system inoperable, place the inoperable channel in the downscale tripped condition I

within v. g

b. With two of the require monitors in a trip system inoperable, establish SECONDARY CONTAINMENT INTEGRITY with at least one standby gas treatment subsystem operating within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

GRAND GULF-UNIT 1 3/4 3-61 Amen 2 md Mo. l

TABLE 4.3.7.1 a RADIATION MbHITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS h

o OPERATIONAL CHANNEL _ CONDITIONS FOR 8 .. CHANNEL FUNCTIONAL CHANNEL WHICH SURVEILLANCE q; INSTRUMENTATION CHECK TEST CALIBRATION REQUIRED

' 1. Component Cooling Water Radiation E Monitor. S M A At all times p 2. Standby Service Water System ,

,_. Radiation Monitor 5 M A 1. 2, 3, and"

3. Plant Service Water System ^

Radiation Monitor S M A #

4. [ DELETED]

5. Carben Bed Vault Radiation Monitor S M A 1, 2

6. Control Room Ventilation Radiation Monitor S pQ M ) A 1, 2, 3, 5 and**

7. Containment and Drywell Ventilation w Exhaust Radiation Monitor S -Q R A At all times

8. Fuel Handling Area Ventilation >

Y Radiation Monitor S A 1, 2, 3, 5 and**

R 9. Fuel Handling Area Pool Sweep 9 fX Exhaust Radiation Monitor S 9,X A (b)

10. Area Monitors

a. Fuel Handling Area Monitors 1) 2)

New Fuel Storage Vault Spent Fuel Storage Pool S M R (c) gy S M R (d) e et

3) Dryer Storage Area S M R (e) *$

b. Control Room Radiation Monitor S M R At all times G[

With RHR heat exchangers in operation.

o$

p

. *(a*) When irradiated fuel is being 5andled in the primary or secondary containment. gw The CHANNEL FUNCTIONAL TEST shall demonstrate that control room annunciation occurs if any of the following <t a conditions' exist.

5 1. Instrument indicates measured levels above the alarm / trip setpoint. 9 5 2. Circuit failure. 9 z 3. Instrument indicates a downscale failure.

? 4. Instrument controls not in Operate mode. ?

y ui (b) With irradiated fuel in the spent fuel storage pool. -

N

? (c) With fuel in the new fuel storage vault. 8 (d) With fuel in the spent fuel storage pool. o (e) With fuel in the dryer storage area. e

With ADHR heat exchangers in operation.

k

c

~

_ -TABLE 3.3.8-1

[ ~ PLANT SYSTFMS ACTUATION INSTRUMENTATION iE~ MINIMUM APPLICABLE 5

. OPERABLE'CHANN ' OPERATIONAL:

y - TRIP FUNCTION. PERTRIPSYSTEMg CONDITIONS ACTION

-[ 1. CONTAINMENT SPRAY SYSTEM

a. Drywell Pressure-High '2:- .1,'2, 3 -130

. b. Containment Pressure-High -1 1 , 2 ,' 3 131 c.- Reactor Vessel Water Level-Low

-Low Low, Level 11 2 1,2,3 130

- d .' Timers'. .

1): System A 1 1,'2, 3 131'

2) System B

'l 1,2,3 131

$ 2. FEEDWATER SYSTEM / MAIN TURBINE TRIP' SYSTEM

a. Reactor Vessel Water Level-High, Level 8 3 1: 132

3. SUPPRESSION POOL MAXEUP SYSTEM

a. Drywell Pressure :High (ECCS)' 2 1, 2, 3 ' 135 .y>

b. Drywell Pressure - High (RPS)- 2 1 , 2 . 3 .. 135 j#n-

c. Reactor Vessel Water Level - Low - g P3 Low Low, Level.1 -

2 1,2,3 -135 = g;

d. Reactor Vessel Water Level'- Low

,3I Low, level 2 2 1,2,3 A5 135 yw

$ e. ' Suppression Pool Water Level - Low Low 1 1,2,3 133~

er

= 0

% f. Suppression' Pool Makeup Timer 1 1,2,3 133 9 f g. SPMU Manual" Initiation 2 1,2,3 m

134- I Ls*A R

[ '(a)A channel may be placed-in an ' inoperable status for up to-2-heurs.during periods of- required S l

~

-surveillance provided~at least one other OPERABLE channel in the same trip system is 8 monitoring that parameter. *

, , _ . . . _ _ _ _ m _.. . -. _m, _. -

Attachment 3'to GNRo-92/00099 Page 19 of 39 2 INSERT TO PAGE 3/4 3-93

' ~

hours (2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for the Reactor Vessel Water Level - High, Level 8 instrumentation) 4 i

1 i

awn.a . ~.

Attachment 3 to GNRO-92/00099 Pago 20 of 39 TABLE 3.3.B-1 (Continued)

PLANT SYSTEMS ACTUATION INSTRUMENTATION, ACTION ACTION 130 - a. With the ntanber of OPERABLE channels one less than required by the Minimum GPERABLE Channels per Trip System requirement, o place the inoperable channel in the tripped condition within f4gv[Acc:h=;otherwise,declaretheassociatedcontainment 1 spray system inoperable and take the action required by Tech-nical Specification 3.6.3.2.

b. With the nucher of OPERABLE channels two less than required by the Minimum OPERABLE channels per Trip System require" ment, declare the associated containment spray system inoperable and tske the action required by Technical Specification 3.6.3.2.

ACTION 131 - With the i. amber of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, restore the inoperable channels to OPERABLE status within one hour other-wise, declare the associated containment spray system inope;rable and take the action required by Technical Specification 3.6.3.2.

ACTION 132 - For the feedwater system / main turbine trip systes:

a. With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels requirement, restore the inoperable channel to OPERABLE status within 7 days or be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

b. With the number of OPERABLE channels two less than required by the Minimum OPERABLE Channels per Trip System require-ment, restore at least one of the inoperable channels to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 133 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, declare the associated suppression pool makeup system inoperabl and take the action required by Specification 3.6.3.4-29 ACTION 134 - With the number of OPERABLE channels less thr.a requ red by the Minimus OPERABLE Channels per Tria System require t, restore the inoperable channels to OPERABLE status within hours; other- l wise, declare the associated suppression pool makeup systes inoperable and take the action required by Specification 3.6.3.4.

ACTION 135 - With the number of OPERABLE channels less than required by the Minimum GPERABLE Channels per Trip Function requirement:

a. With one channel inoperable, place the inoperable channel in the tripped condition within :..c ' ue or declare the I associatedsystes(s) inoperable. p

b. With more than one channel inoperable, declare t e associated system (s) inoperable.

GRAND GULF-UNIT 1 -

3/4 3-94 Amendment No. 69, 87 f -

$ TABLE 4.3.8.1-1 5

g E PLANT SYSTEMS ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS ch 5 CHANNEL OPERATIGNAL CHANNEL FUNCTIONAL CHANNEL

[ TRIP FUNCTION CHECK CONJITIONS IN WHICH TEST CALIBRATION 53JRVEILLANCE REQUIRED

1. CONTAINMENT SPRAY SYSTEM

a. Drywell Pressure-High N ,

S hO l b.

c.

Contairment Pressure-High S h4{, R R

1,2,3 1,2,3 I

Reactor Vessel Water Level -

Low Low Low, Level 1- S h4 J

d. Timers R(a) 1, 2, 3 NA X Q 1, 2, 3

2. FEEDWATER SYSTEM /MA D TURBINE TRIP

{ SY5ftM w a. Reactor Vessen dater Level-High, g Level 8 5 M R 1

3. SUPPRESSION POOL MAKEUP SYSTEM

a. Drywell' Pressure - High (ECCS) S ,

R(a) 1, 2, 3 b.

2%

Drywell Pressure - High (RPS) S MQ.l R(a) 1, 2, 3

c. Reactor Vessel Water Level - Low Low Low, level 1 "E S hQ R(*) 1, 2, 3 SS F d. Reactor vessel Water Level - Low '

{ Low, level 2 0" S

KQ R(a) 1, 2, 3 $

Supp.ession Pool Water Level -

e.

low Low S ,KQ R(a) 1, 2, 3 h

o

f. Suppressiop Pool Makeup Timer NA KQ Q 1,2,3 *

% g. SPMU Manual Initiation NA R NA I 1,2,3

O c

}.

O l (a) Calibrate trip unit at least once per 3s days. w I

[ y,-

k Attachment 3 to GNRO-92/00099 Page 22 of 39

REACTOR COOLANT SYSTEM 3 /4. 4'. 2 SAFETY _ VALVES

. SAFETY / RELIEF VALVES LIMITING CONDITION FOR OPERATION 3.4.2.12 For the-followiag safety / relief valves:

a.- The safety valve function of at least 7 valves and the relief valve function of at least 6 valves other than those satisfying the safety va)ve function requirement shall be OPERABLE with the specified lift settings, and

b. The safety / relief tail pipe pressure switches for each safety / relief valve shall be OPEPABLE. ~

Numbsr of Valves Function Setpoint* (psig) 8 Safety. -1165 + 11.6 psi 6 Safety 1180 7 11.8 psi 6 Safety 1190 7 11.9 psi 1 Relief 1103 7 15 psi

=

10, Relief- 1113 7-15 psi 9

Relief 1123-315 psi APPLICABILITY: OPERATIONAL-CONDITIONS 1, 2 and 3.

~

ACTION:.

a. With the safety and/or relief valve function of one or more of the above required safety / relief valves inoperable, be in at least H0Y SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. With one or more safety / relief- valves ~ stuck open, provided that suppres-sion pool average water temperature is less than 110*F, take action to close the stuck open relief valve (s); if suppression pool average. water temperaturn is 110'F. or greater,-place the reactor mode switch in the o Shutdown position. - -

c. With_one or more safety / relief tail pipe pressure switches inoperable, restore the inoperable- switch (es) to OPERABLE status within 7 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

d. With either relief valve function pressure actuation trip system "A" or

"B" inoperable, restore the inoperable trip systes to OPERABLE status

)

within 7-days; otherwise be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTOOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS -4.4.2.1.1 The tail pipe pressure switch for each safety / relief valve shall be

demonstrated-OPE""ZC with the setpoint verified to be 30 t 5 psig by l performance of a:

' o P E RA B L. f.,y, w

The-lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.

Initial_ooening of 1B21-F051B is 1103 + 15 psig due to low-low set function.

~

I AJAEAT' 3/4 4-5 Amendment No. 2 !, _

D GU F-UNIT 1 1

At.tachment 3 to GNRO-92/00099 Page 23 of 39 INSERT TO PAGE.3/4 4-5 i

- . A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system-in the tripped condition.

t 4

1 1

httcchmont 3 to GNRO-92/00099 REACTOR COOLANT SYtt,EM

$URVE!LLANCE REQUIPEMEkf5 (Com<nued) ~

^- 4. CHANNEL FUNCTIONAL TEST at least once per days, and a l ODWI- b. CHANNEL CALIBRATION at least once per 18 months."

4.4.2. The relief valve fune. tion pressure actuation instrumentation shall be demonstra 4P DA0!.i by pe tormance of at l

a. CHANNCL FUNCTIONAL TEST, including cat tbratiot of the trip unit, at least once per days.. j

b. CHANNEL cal.1 BRAT ON, LOGIC SYSTEM FUNCTIONAL TEST and simulated automatic operation of the entire system at least once per 18 months.

r

-4 4

4 '

"The provisions of Specification 4.0.4 are not applicable provided the surveillance is performed within-12 hours after reactor-steam pressure is adequate to perform the test.

3.a S E AT

. .i?ASD GULF-UNIT 1 3/4 4-6 I\Me d *cs 04 0 . -

Pago 25 of 39 l

INSERT TO PAGE 3/4 4-6 I

- A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition.

J l

. _ __ _ _ _~ _

Attachment 3 to GNRCe-92/00099 Page 26 of 39 REACTOR COOLANT SYSTEM SAFETY / RELIEF VALVES LOW; LOW $ET FUNCTION L!HITikG CON 0! TION FO't OPERATION 3.4.2.2 The relief valve function and the low-low set function of the following reactor coolant system safety / relief valves shall be OPERABLE with ta f ollowing low-low set function lif t settings:

Setpoint* (psig) t 1$ usi Valve No. Open Close F0510 1033 926 F0518 1073 936 F0470 1113 946

. F047G 1113 946 F051A 1113 946 F051F 1113 946 APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

I,CTION:

a. . With the relief valve function and/or the low-low set fui.ction of one of the above required reactor coolant system safety / relief valves inoperable, restore the inoperable relief valve function and the low-low set function to OPERABLE status within 14 days or be in at least HOT SNUT00W within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. With the relief valve function and/or the low-hw set function of more than one of the above required reactor coolant systaa safety / relief valves inoperable, be in at least HOT SHUTDOVH within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD

$ HUT 00WN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

c. With either relief valve / low-low set function pressure actuation trip systen " A" or "B" inoperable, restore the inoperable trip systen to OPERABLE status within 7 days; otherwise, be in at least HOT SHUT 00WN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS s

.m_ ~

MR A 6L E. *

4.4.2.2.1 The relief valve function and the low-low set [nct n pressure actuation instrumentation shall be demonstrated OPEnASth)by performa l

4. CHANNEL FUNCTIONAL TEST, including calibration of the trip unit, at least once per ays, j b, CHANNEL BRAT 10N, LOGIC SYSTEM FUNCTIONAL TEST and simulated automatic operation of the entire systes at least once per la months.

"The lif t setting pressure shall correspond to amoient conditions of the valves at neninal operating temperatures and pressures, I "CNSEA RAN LF-UNIT 1 3/4 4-7 4e&c + ib. _.__

Attachment 3 to G!4RO-92/00099 Page 37 of 39 INSERT TO PAGE 3/4 4-7

- A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip 1

system in the tripped condition.

l

- I

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(

Attachment 3 to G11RO-92/00099 pago 28 of 39 EMERGENCY _ CORE COnllNG SYSTEMS LlHITING CONDITION FOR OPERATION _,(Continued)

ACTION: (Continued)

c. With one suppression pool water level instrumentation divis an inoperable, restore the inoperable division to OPERABLE status within 7 days or verify the suppression pool water level to be greater than or equal to 18'4-1/12" or 12'8", as applicable, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by an alternate indicator,

d. With both suppression pool water level instrumentation divisions inoperable, restore at least_one inoperable division to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTOOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and verify the suppression pool water level to be greater than or equal to 18'4-1/12" or 12'8", as applicable, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by at least one alternate indicator.

SUR,VEILLANCE REQUIREMENTS 4.5.3.1 The suppression pool shall be determined OPERABLE by verifying:

a. The water level to be greater than or equal to, as applicable:

1. 18'4 1/12" at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2. 12'8" at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

b. Two suppression pool water level instrumentation divisions, with I channel per division, OPERABLE with the low water level alarm setpoint > 18'5Y'% 12'S", n appMoaMe3 by performance of a: 1

1. CHANNIL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

2. CHANNEL FUNCTIONAL TEST at least once per 31 days, and

3. CHANNEL CALIBRATION at least once pe- 18 months.

( sa '

4.5.3.2 With the suppression pool level less than the above limit or drained in OPERATIONAL CONDITION 4 or 5*, at least once per 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s:

a. Verify the required conditions of Specification 3.5.3.b to be satisfied, or

b. Verify footnote conditions

to be satisfied.

-fnxc4 2.

GRAND GULF-UNIT 1 3/4 5-9 Amendment No. 69

Attachment 3 to GNRO-93/00099 Page 39 of 39 i

i INSERT 1 TO PAGE 3/4 5-9

c. Two cuppression pool water level inntpumantation divisions, with 1 .hannel por division, OPERABLE with the low water lovel alarm notpoint 2 12'8" por performance of at j 1, CilANNEL CHECK at least onco por 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

2. CllANNEL FUNCTIONAL TEST at least onco por 92 days, and

3. CllANNEL CALIBRATION at least onco por 18 months.

INSERT 2 TO PAGE 3/4 5-9

/ A channel may t',1:1 ,.go <.r an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months during jp-;.:rgy'a of retiaired survol11ance provided at least one other OP6RABLE channel in the same system is monitoring that perameter.

l-

Attachment 3 to cimo-92/00099 Page 30 of 39 INSTRUKENTATION -

BASES RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION (Continued)

Each EOC RPT adrainistratively system may be manually bypassed by use of a keyswitch which is controlled.

Bypass room.

at less than 40% of RATED THERML POWER are annunciat The automatic bypass setpoint is feedwater temperature dependent due to the subcooling chan power relationship.ges that affect the turbine first stage pressure reactor For RAfED THERHAL POWER operation with feedwater tempera-ture greater than or equal to 420'F, an allowable setpoint of < 26.9% of control valve wide open turbine first stage pressure is provided for tKe bypass func-tion. This setpoint is also applicable to operation at less than RATED THERHAL POWER with the correspondingly lower feedwater tegerature. The allowable set-point is reduced to < 22.5% of control valve wide open turbine first-stage pres-sure for RATED THERMXL POWER operatinn with a feed <ater temperature between LW(]'# 370'F and 420'F. Similarly, the reduced setpoint is applicable to operation at less than RATED THERHAL POWER with the corresponding lower feedwater temperature.

The EOC-RPT system response time is the time assumed in the analysis I between i.e., 190 initiation as. Includedof valve motion and complete suppression of the electric arc, in this time are: the response time of the sensor, the

response time of the system logic and the breaker interruption tire. Breaker interruption time includes both breaker response time and the manufacturer's design arc suppression time of 12 ss, Operation with a trip set lets conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater then the drift allowance assumed for each trip in the safety analyses.

3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMEN The reactor core isolation cooling system actuation instrumentation is provided to initiate actions to assure adequate core cooling in the event of reactor isolation from its primary beat sink and the loss of feedwater flow to

'IM 2 the reactor vessel without providing actuatica of any of the emergency core cooling equipment, 1

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the dif ference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

3/4.3.6 CONTROL R00_ BLOCK INSTRUMENTATION The control rod block functions are provided consistent with the require-ments of the specifications in Section 3/4.1.4, Control Rod Program Controls and Section 3/4.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will results in a control rod block.

The OPERABILITY of the contrcl rod block instruasntation in OPERATIONAL CONDITION 5 is to provide diversity of rod block protection to the one-rod-out interlock.

GRAND GutF-UNIT I B 3/4 3-3a Amendment No. 97,-

pwr--,yer- ,_r --m --

g . - - - y-- -y- - -_ - -

Attachment 3 to GliRo-93/00099 Pago 31 of 39 IllSERT 1 TO PAGE B 3/4 3-3a Specifiod survoillance intervals and surveillance and maintenance outage times have boon determinod "

in accordance with General Electric Report GE!1E-770-06-1, Bases for changes to survalliance Test Intervals and Allowed Out-of-Sorvice Times for Selected Instrumentation Technical Specifications", February 1991.

IllSERT 2 TO PAGE 3/4 5-3a Specified surveillanco intervals and surveillanco and '

maintenance outage timos havo been determined in accordanco with General Electric Report GEllE-770-06-2, " Addendum to Bases for Changes to surveillanco Test Intervals and Allowed Out-Of-Service Times for Selected Instrumentation Technical Specifications",

February 1991. .

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Attachment 3 to CHRO-92/00099 INSTRtMENTATION Pago 32 of 39 SA$f5 3/4.3.6 CONTROL R00 BLOCK !NSTRUMENTATION (Continued)

Specified surveillance intervals have been detemined in accordance with t NEDC 30851P A, supplement 1, " Technical specification Improvement Analysis for 8WR Control Rod Block Instrumentation" as approved by the NRC and documented in the NRC $afety Evaluation ort ( tter to D. N. Grace from C. E. Rossi dated September 22,1988). Lyd .} l Operation with a trip set less conservative than its Trip Setpoint but within its'specified Allowable Value is acceptable on the basis thct the difference betwoon each Trip-Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

3/4.3.7 MONITORING-lNSTRUMENTATION 3/4.3.7.1 RADIATION MONITORING INSTRUMENTATION

-The OPERA 8ILITY of the radiation monitoring instrumentation ensures that:

(1) the radiation levels are continually measured in the areas served by the individual channels; (2) the alarm or automatic action is initiatsd when the -

radiation level trip setpoint is exceeded; and (3) sufficient information is-available on selected plant parameters to monitor and assess these variables "I nW4g following an accident. This capabllity is consistent with the recommendations of NUREG 0737, " Clarification of TM1 Action Plan Requirements," November. -1980.

3/4.3.7.2 SEl$MIC MONITORING INSTRUMENTATION The 0PERABILITY of the seismic monitoring instrumentation ans cas that sufficient capability is available to promptly determine the magnitude of a seismic event. and evaluate the response of those features important to safety.

This-capability is required to permit comparison of the measured response to that used in the design basis for the unit. '

3/4.3.7.3 METEOROLOGICAL MONITORING INSTRUMENTATION The OPERA 81LITY of the meteorological sonitoring instrumentation ensures that sufficient meteorsiegical data are available for estinating potential radiation doses to the public as a result of routine er accidental release of radioactive asterials to the atmosphere.- This capability is required to evaluate the need for initiating protective esasures to protect the health and safety _.of the public. This instrumentation is consistent with the recommenda-tions of Regulatory Guide 1.23 onsite Meteorological Programs," February,1972.

-3/4.3.7.4 REMOTE $MUT00WN $YSTEM 1NSTRUMENTAT10N AND CONTROL 5 The OPERABILITY of the remote shutdown -systes instrumentation and controls asures _that sufficient capability is available to pemit shutdown and main-tenance of H0T $ HUT 00WN of the unit from locations outside of the control room. ,

-This capability is required in the event control room habitability is lost and

-is consistent with General Design Criterion 19 of 10 CFR 50.

GRAND GULF-UNIT 1 8 3/4 3-4 Amendment No. 41, H ,

)

--___-__-_-__-_-___-___w

Attachment 3 to GNRO-93/00099 Page 33 of 39 INSERT 1 TO PAGE B 3/4 3-4 Specified surveillance and maintenance outage timos have boon dotormined in accordanco with consral Electric Report GENE-770-06-1, " Basos for Changos to Survo111ance Test Intervals and Allowed Out-Of-Sorvico Times for Selected Instrumentation Technical Specifications", February 1991.

INSERT 2 TO PAGE 3/4 3-4 Specified surveillance intervals and survoillanco and maintenanco outage times have boon determined in accordance with Conoral Electric Report GENE-770-06-1, " Bases for Changos to survoillance Toot Intervals and Allowed out-of-Sorvico Times for Selected Instrumentatior, Technical Specifications", February 1991. -

At.tachment 3 to G!mo-9?/co099 pago 34 of 39 INSTRUMENTATION BASES 3/4.3.7.10 LOOSE-PART DETECTION $YSTEM The OPERABILITY of the loose part detection system ensures that sufficient capability is available to detect loose metallic parts in the primary system and avoid or sitigate damage to primary systta coaronents. The system consists of 16 sensors, of which only 8 are selected and need to be OPERABLE at a time to provide the inputs to the 8 monitoring channels. The remaining 8 sensors may be used as replacement s6nsor inputs for failed sensors or to provide a )

change in location of the area being monitored.

The allowable out-of-service times and surveillance Guide 1.133 requirteents are consistent with the recoenendations of Regulatory '

, of Light Vater-Cooled keactors," May 1981."Loost Part Detection Program for t 3/4.3.7.12 MAIN CONDENSER 5Y5IEM INSTRUMERTATIUN 0FFGAS TREATHENT SYSTEM - EXPLOSIVE The explosive gas monitoring system instrumentation of the main condenser off-explosive gas mixtures in the main condenser offgas This treatment instrumentation is calibrated in accordance with plant procedures.

3/4.3.8_ PLANT SYSTEMS ACTUATION INSTRUMENTATION The plant to mitigate systems actuation instrumentation is provided to initiate action the conse operator to control. quences of accidents that are beyond the ability of the on a hi The LPCI mode of the RHR system is automatically initiated signal.gh drywell pressure signal and/or a low reactor water level level 1 high dryvell and high Containment pressure signals.Thecontainmentspr Negative barometric pres-sure fluctuations are accounted for in the trip setpoints and allowable values specified for drywell and containment pressure high. A 10-minute minimum 13-minute maximum time delay exists between initiation of LPCI and contain, ment spray actuation. A high reactor water level level 8 signal will actuate the feedwater system / main turbine trip system. Ihe suppre,ssion pool makeup system is automatically initiated on a low low suppression pool water level signal with a concurrent LOCA signal. LOCA signal or following a specified time delay after receipt of a The low low suppression pool water level Trip Setpoint and Allowable Value are relative to the surface floor of the suppression pool (93'0\" above mean sea level).

M se.c-t l GRAND GULF-UNIT 1 B 3/4 3 6 Amendment No. 6, 87, l

_ . . _ .._.___.m. . . . _ _ . _ _ - . . _ . _ . _ _ _ . _ _ . . _ . _ _ _ _ _ . , _ _ . _ _ _ _

f Attachment 3 to G!1RO-92/00099 Pago 35 of 39 e

INSERT.TO PAGE B 3/4 3-6 Specified surveillance intervals and surveillance and maintenance outage titnes have boon determined in accordance with l General Electric Report GENE-770-06-1, " Bases for Changos to f Surveillance Test Intervals and Allowed out-of-Servico Times for >

Selected Instrumentation Technical Specifications", February 1991.

E 1

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-Attachment 3 to G!1RO-93/00099 Pago 36 of 39 o- RIAC70R COOLANT SYSTEM BASE 5 3/4.4.2 SAFETY / RELIEF VALVf5 The safety valve function of the safety /reifef valves (SRV) operate to prevent the reactor coolant system from being pressurized above the Safety Limit of 1325 psig in accordance with the ASME Code. A total of 13 OPERA 8LE safety /

relief valves is required to limit reactor pressure to within ASME !!! allowable values for the-worst case upset transient.

in the relief mode and 7 SRVs operating in the safety mode is acesplable.An Demonstration of the safety / relief valve lift settings will occer only during shutdown and will be performed in accordance with the provisions of Specification 4.0.S.

The Iw 1w set systes ensures that safety / relief valve discharges are minimized for a second opening of these valves following any overpassure transient. Thisisachievedbyautomaticallyloweringtheclosingsetpointof'

- 6 valves and lowering the opening setpoint of 2 valves-following the initial opening. In this way, the frequency and segnitude of the cents' duty cycle is substantially reduced. Sufffctent redundancy is provided neent blowdown for the Iw low set systen such that failure of any one valve to open or closa at '

y its_ reduced _setpoint does not violate the design basis.

g l

g g 3/4.4 3 REACTOR COOLANT SYSTEM LEAKAGE

, 3/4.4.3.1 LEAKAGE DETECTION SYSTEMS The RCS leakage detection systees required by this specification are provided to monitor and detect leakage free the reactor coolant pressure boundary. These systees provide the ability to sessure leakage from fluid systems in the drywell.

I 3/4.4.3.2 0FERAT10NAL LEAKAGE The allowable leakage rates free the reacter reelant systen have been based on the predicted and experimentally observed behavior of' cracks in pipes. The normally expected background leakage due to equipment design and the detection capability of the instrumentation for determining systes leakage was also con-

.sidered. The evidence obtained free experteents suggests that for leakage seeswhatJereater than that specified for UNIDENTIFIEg LEAKME the probability is small that the leperfection er crack associated with such leakage would grow rapidly. -Hewever,'in all cases, if the leakage rates exceed the values specified

-er the leakage is located and known to be PRE 550RE 300MBARY LEAKAGE th will be shut down te allow further-investigatten and corrective action.e reactor Service sensitive reacter coolant systas Type-304 and-n8 austenitic stainless steel piping, i.e., these that are sub.iest te high stress or that contain relatively stagnant, intamittent, or low flow fluids, requires additional surveillance

and leakage limits.

- The Survel11ance Requirements for RCS pressure isolation valves provide ,

l added assurance of valve integrity,:the reducing the probability of gross t

valve failure and consequent ntersystes . Leakage from the RCS pressure isolation valves is 10Dff!FIED LEAXAGE and will be considered as a portion of the allowed Ilmit.

GRAND GULF-UNIT 1 8 3/4 4 2 g , b d 4,__l E. _ _ , __-.2 - _ - - - - - - - - - - ~ - ' ~ ~

Attachment 3 to GilRO-92/00099 Pago 37 of 39 IllSERT TO PAGE B 3/4 4-2 Speciflod surveillanco intervals and surveill :ico outage timos have boon datormined in accordance with General Electric Report GEllE-770-06-1, " Bases for Changes to Survoillance Test Intervals and Allowed out-of-servico Times for Selected Instrumentation Technical Specifications", February 1991.

--,n., ...- . , , -

Attachment 3 to GilRO-92/00099 Pago 38 of 39 3/4.5 EMERGENCY CORE COOLING SYSTEM EXTET ~

. SUPPRESSION POOL (Continued)

In OPERATIONAL CONDITION 4 and 5 the suppression chamber minimum required water volume is reduced because the reactor coolant is maintained at or below 200'F, Since pressure suppression is not required below 212*F, the minimum required water volume is based on NPSH, recirculation volume, and vortex preven-tion plus a l'2" safety margin for conservatism. -g

.Id5C ET e

e GRAND GULF-UNIT 1 B 3/4 5-3 gg

__ .. ._m._ _. ______._...__.- _ __ .... _ _ .._ _ _ .._.-_ _ . _ .__

i Attachinont 3 to G11RO-93/00099 Page 39 of 39 l IllSERT TO PAGE B 3/4 5-3 [

Speciflod surveillance intervals and survoillance outago ,

times for the wide rango suppression pool water level l Instrumentation have boon datormined in accordance with General

" Dases for Changes to Surveillance Electric Report GE11E-770-06-1, Test Intervals and Allowod Out-of-Servico Times for Selected i Instrumentation Technical Specifications", February 1991. P P

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Attachment 4 to GNRO 92/00099 l Page 1 of 28 !

1 t

i l

- t

-t Sample Proposed Technical Specification Pages

_-i PCOL-92/03 fv ,

'i 1:

Attachment 4 to G%0-92/00099 Pago 2 of 2R J1tBIM[llIAUM

[ 1110f-C101E RECIRCVIA110N PUMP TR]P SYS1[li_IllSIBUMENIA11M LIMITING CONDITION FOR OPERATION

._._ _ n - ,_ --___

3.3.4.2 The end of cycle recirculation pump trip (EOC-RPT) system instrumentation channels shown in Table 3.3.4.2-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.4.2 2 and with the END Of CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME as shown in Table 3.3.4.2-3.

AEf11(AE1111Y: OPERATIONAL CONDITION 1, when THERMAL POWER is greater than or equal to 40% of RATED THERMAL POWER.

AtllM:

a. With an end of-cycle recirculation pump trip system instrumentation channel trip so; aint less conservative than the value shown in the Allowable Values column of Tabit 3.3.4.2-2, declare the channel inoperable until the channel is restored to OPERABLE status with the channel setpoint ' adjusted consistent with the Trip Setpoint value,

b. With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels per Trip System requirement for one or both tri wit iin lnsystems,placetheinoperablechannel(s)inthetripoedcondition 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . I

c. With the number of OPERABLE channels two or more less than required by the Minimum OPERABLE Channels per Trip System requirement for one trip system and:

1. If the inoperable channels consist of one turbine control valve channel and one turbine stop valve channel, 31 ace both inoperable channels in the tripped condition within 121ours. l

2. If the ino,,erable channels include two turbine control valve channels or two turbine stop valve channels,- declare the trip system inoperable.

d. With one trip system inoperable, restore the inoperable trip system to OPERABLE status within 72 hour: or reduce Ti1ERMAL POWER to less than 40% of RATED THERMAL POWER within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

e. With both trip systems inoperable, restore at least one trip system to OPERABLE status within-one hour or reduce THERMAL POWER to less than 40% of RATED THERMAL POWER within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 l

GRAND-GULF-UNIT 1 3/43-41 Amendment No. _ l 1

Attachmont 4 to G!1RO-92/00099 Page 3 of 28 TABLE 3.32 4.2.1 DiD OF-CYCLE pCCIRCULA110N PUMP TRIP SYSTEM INSTRUMENTATION HINIMUM OPERABLE CHANNELS PER N

18]P TVNCT1.0ff TRIP SYSIEM __

1. Turbine Stop Valve Closure 2*)

2. Turbine Control Valvo - Fast Closure 2*)

t (a) A trip. system'may be placed in an ino>erable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for l required surveillance provided that tie other trip system is OPERABLE. r

-(b) This function shall be automatically bypassed when operating-below the appropriate turbine first st]ge pressure setpoint of (1) s 26.9% of the value of turbine first-stage pressure at valves wide open (VWO) steam flow when operating with rated feedwater temperature '

of greater than or equal to 420*F; or '

(2) s 22.5% of the value of turbine first-stage pressure at VWO steam flow 'when operating with rated feedwater temperature between 370*F and 420 F.

These represent allowable setpoint values of turbine first-stage pressure equivalent to THERMAL POWER less than 40% of RATED THERMAL POWER.

GRAND GULF UNIT 11 3/4 3-43 AmendmentNo._16,___l i

Attachment 4 to GNRO-93/00099 Page 4 of 28 INSTRUMENIAll0B IMLI LL 4.2.1 1

[hD 0F-CYCLL.,JJ11RWLAT[Q!LEVliP TRIP SYSTEM EVfLVEILLANCE RE0VIRLMENLS CHANNEL FullCTIOf1AL CHANNEL 181EJ_V3fil03 TDT CALLBfMLL0ff

1. Turbine Stop Valve Closure Q* R'

2. Turbine Control Valve - Fast Closure Q* R'

' including Trip system logic testing.

'Calibratetripunitsandlogicaticastonce,' 92 days. l GRAND' GULF UNIT'l 3/4 3-46' Amendment No. l

h. f

. _- _. x- __

TABLE 3.3.5-1 REACTOR CORE ISOLATION COOLING' SYSTEM ACTUATION INSTRUMENTATION

. MINIMUM FUNCTIONAL UNITS OPERABLE CHANNELS (*) ACTION

a. Reactor Vessel Water Level - Low Low, level 2 4

b. Reactor Vessel _ Water Level - High, level 8 2 51

c. Condensate Storage Tank Water Level -' Low 2 52 J. Suppression Pool Water level - High 2 52

e. Manual' Initiation 1 53 (a) A channel may be placed .'n an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without l placing the trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.

5N

's a m0 oS

%g

$a O

8 a

i R

8 8

. GRAND GULF-UNIT 1 3/4 3-48 Amendment No. 16,

~

Attachment 4 to Gt1Ro-93/00099 Page 6 of 28 INSTRUMENTATIOS TABLE 3.3,5-1 (Continued)

REACTOR CORE ISOL ATION C00l1NG.__SJ.51W AClVATION INSTRWENTATION AC110N 50 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requiremant: j I

a. With one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the RCIC system inoperable. ;

i I

b. With more than one channel inoperable, declare the RCIC system inoperable.

ACTION 51 -- With the number of-OPERABLE channels less than required by the minimum OPERABLE channels requirement, declare the RCIC system inoperable within 24 haurs.- l l

ACTION 52 With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requirement, place at least one '

inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months l or declare the RCIC system inoperable, ,

ACTION 53 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the RCIC l system inoperable.

l 1

l

' GRAND GULF-UNIT 1 3/4 3-49 Amendment No. _ _ l l . _ . . - _ __ _ _ __ . ._ _ _,___ ___, ,._ _ . _ .. _ , _... __ _ .

m TABLE 4.3.5.1-1 REACTOR" CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REGUIREMENTS.

C %NNEL CHANNEL FUNCTIONAL CHANNEL FUNCTIONAL UNITS. ' CHECK TEST CALIBRATION

a. Reactor Vessel Water level - I Low Low, level 2 S Q R(*)

b. Reactor Vessel Water [

Level - High, Level 8 5 Q R l

c. . Condensate Storage Tank Level - Low S 'Q- R

d. Suppression Pool Water Level -

High S Q R I N NA I

e. Manual Initiation NA Q (a) Calibrate trip unit at least once per 92 days. 1 (b) Manual initiation switches shall be tested at least once per 18 months during shutdown. All other circuitry associated with manual initiation shall receive a CHANNEL FUNCTIONAL TEST at least once 2E per 92 days as a part of circuitry required to be tested for automatic system actuation. I jg 4O R.k i

e B

?

1 8

e

' GRAND GULF-UNIT I 3/4 3-51 Amendment No. l

p. ,

Attachment 4 to GNRO-92/00099 Pago 8 of 28 JNSTRUMENlATION 3/4.3.6 C0!ilROL R00 B1QLLiliSTRUMENTAllM LIMITING CONDITION FOR OPERATION =. _ _ _ ,_ _ _,

3.3.6. The control rod block instrumentation channels shown in Table 3.3.61 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.6 2.

AEELLCAE1LJ1Y: As shown in Table 3.3.6 1.

A(llM:

a. With a control rod block instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.6-2, declare the channel inoperable until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value.

b. With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, take the ACTION required by Table 3.3.61.

SURVEILLANCE REQUIREMENTS f%**V 4.3.6 Each of the above required control rod block tri) systems and .

A" ns rumentation channels shall be demonstrated OPERABLE

ay the performance of I W i the CHANNEL CHECK, CHANNEL FUNCTIONAL TES1 and CHANNEL CAllBRATION operations

-4M for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.6-1.

hP -

g(ga

4.3.6.2 ' The provisions- of specification 4.0.4 are not applicable to the Channel Funtion test' hrveillances for the intermediate Range Monitors and the e Source Range Monitors for entry into their applicable OPERABLE CONDITIONS (as specified in Table 4.3.6-1) from OPERATIONAL CONDITION 1, provided the eillances are performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after such entry. ,

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition, provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.

GRAND GULF-UNIT 1 3/4 3-52 Amendment No.

__ _______._._.___________-___.____b__________.__...______._ __.-______a______.-____ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ __.._._____a

~ _

TABLE 3.3.6-1 CONTROL ROD BLOCK INSTRUMENTATION Mir:IMUM APPLICABLE OPERABLE CHANNELS OPERATIONAL C0f2,TIONS ACTION PER TRIP FUNCTION TRIP FUNCTION

1. R00 PATTERN CONTROL SYSTEM 2 1, 2 60

a. . Low Power Setpoint l# 60 2

b. High Power Setpoint

2. APRM

a. Flow Biased Neutron Flux- 6 1 6i Upscale 1, 2, 5 61 6

b. Inoperative 6 I 61 l c. Downscale 6 2, 5 61

d. Neutron Flux - Upscale, Startup

3. SOURCE PANGE MONITORS Mu.' e**N bhe 61 4

e. Defect 6r not full in(*) '

5 d ,4 3 62 2**

4 61

b. Up:.cale(D,' Zee g) ag;\

sqq::t3o, 62 2** 5 4 > 2n 61

c. Inoperative (b) 2** 5 '/ 62 4 Zes 61 ,

d. Downscale(C) 5 62 o <t 2**

TC

4. INTERMEDIATF RANGE MONITORS 6 2, 5 61 ., Q.

a. Detector not full in 6 2, 5 61 s

b. Upscale 6 2, 5 61 E$

c. Inoperatig>. 6 2, 5 61 m" c> =

d. Downscale

<t 0

5. SCRAM DISCHAhGE VOLUME 2 1, 2, 5* 64 1

a. Water Level-High 9

, 3

6. REACTOR COOLANT SYSTEM RECIRCULATION FLOW 64 I ?

3 1

a. Upscale $

3, 4 63 N 2

7. REACTOR MODE SW1ICH SHUTDOWN POSITION 8 8

Amendment No. 69, l GRAND GULF-UNIT 1 3/4 3-53

Attac Tt 4 to GNRO-92/00099 iflSJEyMENTATIQU Pago . ' 28 IMlE 3.3.11 (Continued) .

2111ROL ROD BLQE_J[UiLRQtiGIMlQU M1LQU ACTION 60 - Occlare the RPCS inoperable and take the AC110N required by Specification 3.1.4.2.

ACi10N 61 -

With the number of OPERABLE Channels:

a. One less than required by the Minimum OPERABLE Channels per Trip function requirement, restore the inoperable channel to OPERABLE status within 7 days or > lace the ino)erable channel in the tripped condition wit 1in the next lour.

Two or more less than required by the Minimum OPERABLE b.

Channels per Trip function requirement, place at least one inoperable channel in the tripped condition within one hour.

ACTION 62 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip function requirement, place the inoperable channel in the tripped condition within one hour.

ACTION 63 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip function requirement, initiate a rod block.

ACTION 64 - With the number of_ OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip function requirement, piace the inoperable channel in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

1101El

With more than one control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

OPERABLE channels must be associated with SRMs required OPERABLE per Specification 3.9.2.

5 TJ

]# * # With THERMAL POWER greater than the Low Power Setpoint.

Whenever the related function is tot bypassed as specified in )

rough =(c). J

) W (a) This function shall be automatically bypassed if detector count rate is

> 100 cps or the IRM channels are on range 3 or higher.

(b) This function shall be automatically bypassed when the associated IRM channels are on range 8 or hig'ner.

(c) This function shall be automtically bypassed when the IRM channels are on range 3 or higher.

(d) This function shall be automatically bypassed when the IRM channels at:

on range 1..

GRAND GULF-UNIT 1 3/4 3 54 Amendment No. 69,

TABLE 3.3.7.1-1 (Ccntired) -

~ RADIATION MONITORING INSTRUMENTATION MINIMUM CHANNELS APPLICABLE ALARM / TRIP MEASUREMENT INSTRUMENTATION OPERABLE CONDITIONS SETPOINT RANGE ACTION 4-

10. Area Monitors

a. Fuel Handling Area Monitors

1) New Fuel 1 (e) i 2.5 cR/hr/NA IG-2 to 103mR/hr 72 Storage Vault 3

2) Spent Fuel 1 (f) 12.5 mR/hr/NA 10-2 to 10 mR/hr 72 Storage Pool 3

3) Dryer Storage 1 (g) i 2.5 mR/hr/NA 10-2 to 10 mR/hr 7?

7 Area 3

b. Control Room 1 At all times s 0.5 mR/hr/NA 10-2 to 10 mR/hr 72 Radiation Monitor

)

With RHR heat exchangers in operation.

- When irradiated fuel is being handled in the primary or secondary containment.

Initial s-+ point. Final Setpoint to be determined during startup test program. Any required change to this setp, nt shall be submitted to Commission within 90 days after test completion.

1. With ADHR heat exchangers in operation. -s ::,

j (a) Trips system with 2 channels upscale-Hi Hi Hi, or one channel upscale Hi Hi Hi and one channel downscale or $$

oa 3

2 channels downscale.

(b) Isolates containment /drywell purge penetrations. e (c) With irradiated fuel in spent fuel storage pool. 3 (d) Also isolates the Auxiliary Building and Fuel Handling Area Ventilation Systems.

(e) With fuel in the new fuel storage vault.

Q

-(f) With fuel in the spent fuel storage pcol. $^

e (g) With fuel . in the dryer storage area. g (h) Two upscale Hi Hi, one upscale Hi Hi and one downscale, or two downscale signals from the same trip system actuata the trip system and initiate isolation of the associated isolation valves. A channel may @

be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system y in the tripped condition, provided at least one other OPERABLE channel in the same trip system is monitoring that i parameter. $

x 8

GRAND GULF-UNIT 1 3/4 3-60 Amendment No. 59, l

E -

Attachment 4 to G!1RO-92/00099 Pago 12 of 28 ELSlRUMENTAUM

.TRlf 3.3.7.1 1 (Continued)

{tADI AT.0N MONITORING INSTR lLMMTAT103 EUM ACTION 70 - With the required monitor inoperable, obtain and analyze at least one grab sample of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 71 -

[ DELETED]

ACTION 72 - With the required monitor ino3erabic, perforn area surveys of the monitored area with porta)1e monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 73 -

a. With one of the required monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; restore the inoperable channel to OPERABLE l status within 7 days, or, within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , initiate and maintain operation of at least one control room emergency :

filtration system in the isolation mode of operation.

b. With both of the required monitcrs in a trip system inoperable, initiate and maintain operation of at least one control room emergency filtration system in the isolation mode of operation within one hour.

ACTION 74 -

a. With one of the required monitors in a trip system inoperable, place the-inoperable channel in-the downscale tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . I

b. With two of the required monitors in_a trip system inoperable, isolate the containment and drywell purge and vent penetrations within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 75 -

a. With one of the required monitors in a trip system inoperable, place the inoperable channel in the downstale tripped condition

' thin 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . I

. With two of the required monitors in a trip system inoperable, establish SECONDARY CONTAINMENT INTEGRITY with at least one standby gas treatment subsystem operating with_in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

l

. GRAND' GULF-UNIT 1 3/4 3-61 Amendment P

y. :-- -

TABLE 4.3.7.I-I RADIATION MONITORING INSTRUNCNTATION SURVEILLANCE REQUIREMENTS OPERATIONAL CHANNEL CONDITIONS FOR CHANNEL WHICH SURVEILLANCE CHANNEL FUNCTIONAL' TEST CALIBRATION RE0UIRED CHECK INSTRUMENTATION

1. Component Cooling Water Radiation S M A At all times Monitor

2. Standby Service Water System M A 1, 2, 3, and*

S Radiation Monitor

3. Plant Service Water System A #

S M Radiation Monitor

4. [ DELETED] S M A 1, 2

5. Carbon Bed Vault Radiation Monitor

6. Control Room Ventilation Radiation S Q(*) A 1, 2, 3, 5 and** !

Monitor

7. Containment and Drywell Ventilation A At all times i l

S Q l Exhaust Radiation Monitor Fuel Handling Area Ventilation 1, 2, 3, 5 and** I

! 8. S Q A Radiation Monitor

9. Fuel Handling Area Pool Sweep A (b) j S Q Exhaust Radiation Monitor

10. Area Monitors

a. Fuel Handling Area Monitors M R (c)

S l 1) New Fuel Storage Vault M R (d)

S

2) Spent Fuel Storage Pool M R (e) y 3, 5

3) Dryer Storage Area .

S H R At all times jg i b. Control Room Radiation Monitor a

~y

With RHR heat exchangers in operation. "g When irradiated fuel is being handled in 'i,' primary or secondary containment.v-te that controi room annunciation (a) The CHANNEL FUNCTIONAL TEST shall demonn conditions exist. g*

1. Instrument indicates measured levels above the alarm / trip setpoint. e

2. Circuit failure.

i

3. Instrument indicates a downscale failure. 9

4. Instrument controls not in Operate mode. 5 (b) With irradiated fuel in the spent fuel storage pool. ?

l (c) With fuel in the new fuel storage vault. 3 I (d) With fuel in the spent fuel storage pool. 's (e) With fuel in the dryer storage area. 8

With ADHR heat exchangers in operation. 8 Amendment No. 59, ["

GRAND GULF-UNIT 1 ,

3/4 3-13

~

. TABLE =3.3.8-1 :-

~

PLANT SYSTEMS ACTUATION INSTRUMENTATION MINIMUM' APPLICABLE-OPERABLE CHANNELS OPERATIONAL TRIP FUNCTION PER TRIP SYSTEMfa) . CONDITIONS ACTION .,

1. CONTAINMENT SPRAY SYSTEM

a. Drywell Pressure-High- 2 1, 2, 3 - 130-

b. Containment Pressure-High 1 1,2,3 13I

c. Reactor Vessel Water Level-Low Low Low, Level I- 2 1,2,3 130

d. Timers

1) System A 1 1,2,3 131

2) System B 1 1,2,3 131

2. FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM

a. Reactor Vessel Water Level-High, Level 8 3 1 132

3. SUPPRESSION POOL MAKEUP SYSTEM

a. Drywell Pressure - High (ECCS) 2 1,2,3 135

b. Drywell Pressure - High (RPS) 2 1,2,3 135

c. Reactor Vessel Water Level.- Low y$

Low Low, Level 1 2 1,2,3 135 gg'

d. Reactor Vessel Water Level - Low Er Low, Level 2 2 1,2,3 J" "E

O3

e. Suppression Pool Water Level - Low Low 1 1,2,3 133 ua Suppression Pool Makeup Timer 1,2,3 *

f. 1 133 r o

g. SPMU Manual Initiation 2 1,2,3 134 c3 5

?

(a)A channel may be placed -in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for the Reactor Vessel Water Level EI

- High, Level 8 instrumentation) during periods of required surveillance provided at least one other OPERABLE 's channel in the same trip system is monitoring that parameter. 8 8

e GRAND GULF-UNIT 1 3/4 3-93 Amendment No. 60, 87, l

=

Attachment 4.to GNRO-92/00099 Page 15 of 28 TABLE 3.3.8-1 (Continued)

PLANT SYSTEMS ACTUATION INSTRUMENTAT10N ACTION

'ACT10N 130 - a. 'With the-number of OPERABLE channels one less than required by the Minimum OPERABLE Chanaels per Trip System requirement, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; otherwise, declare the associated containment l spray system inoperable and take the action required by Tech-nical Specification 3.6.3.2.

b. With the number of OPERABLE channels two less than required by the Minimum OPERABLE channels per Trip System require ment, declare the associated containment spray system inoperable anc take the action required by Technical Specification 3.6.3.2.

ACTION 131 - Witi. A number of OPERABLE channeis less than required by the

' Minimum OPERABLE Channels per Trip System requirement, restore the inoperable channels to OPERABLE status within one hour; other wise, declare the associated containment spray system inoperable and take the action required by Technic?1 Specification 3.6.3.2.

ACTION 132 - For the feedwater system / main turbine trip system:

a. With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels requirement, restore the inoperable channel to OPERABLE status within 7 days or be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . .

b. With the number of OPERABLE channels two less than required by the Minimum OPERABLE Channels per Trip System require ment, restore at least one of the inoperable channels to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 133 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, declare the associated suppression pool makeup system inoperable and take the action required by Specification 3.6,3.4.

ACTION 134 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, restore

.the inoperable channels to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; other 1 wise, declare the associated suppression pool makeup system inoperable and take the action required by Specification 3.6.3.4.

ACTION 135 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:

a. - With one channel inoperable, place the inoperable channel in .the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the l associated systein(s) inoperable.

U b. With more than one channel inoperable, declare the

tsociated system (s) inoperable.

' GRAND GULF-UNIT 1 3/4 3-94 Amendment No. 69. S7, l

t.

-TABLE '4.3.8.'l-1' ..

PLANT' SYSTEMS ACTUATION INSTRUMENTATION SURVEILLANCE RE0VIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL- CHANNEL CONDITIONS IN WHICH CHECK ' TEST CALIBRATION SURVEILLANCE REQUIRED TRIP FUNCTION:

1. CONTAINMENT SPRAY 5YSTEM

a. .Drywell Pressure-High S Q R(*) 1, 2, 3

b. Containment Pressure-High S Q R(*} I, 2, 3

c. Reactor Vessel Water Level -

Low Low Low, Level 1 5 Q R(*) 1, 2, 3-1, 2, 3

d. Timers. NA Q 'Q

2. FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM

a. Reactor Vessel Water ~ Level-High, S M R 1 Level 8

3. SUPPRESSION POOL MAKEUP SYSTEM

a. Drywell Pressure - High (ECCS) S Q R(") 1, 2, 3

b. Drywell Pressure - High (RPS) S Q R(*) 1, 2, 3 yg c et 0*

c. Reactor Vessel Water Level - Low Low Low, level 1 S Q R(*} 1, 2, 3 gh o

P,,5

d. Reactor Vessel Water Level - Low-Low, Level 2 S Q R(^) 1, 2, 3 y3 m

e. Suppression Pool Water Level - Low Low S Q R(*} I, 2, 3 o

f. Suppression Pool Makeup Timer NA Q Q 1, 2,.3 .

?

g. SPMU Manual' Initiation NA R NA 1,2,3 g o

o (a) Calibrate trip unit. at least once per' 92 days. o GRAND GULF-UNIT 1 3/4 3-96 Amendment No. 6'O, 87,

REACTDR COOLANT SYST @ $g 28 3/4.4.2 SAFETY VALVES SAFETY /REllEF VALVES LIMITING CONDITION FOR OPERATION 3.4.2.1 For the following safety / relief valves:

a.1he safety valve function of at least 7 valves and the relief valve function of at least 6 valves other than those satisfying the safety vahe function requirement shall be OPERABLE with the specified lift settings, and

b. 'he safety / relief tail-pipe pressure switches for each safety / relief valve shall be OPERABLE.

Number of Valves function .S_etpoint* (psial 8 Safety 1165 : 11.6 psi 6 Safety 1180 11.8 psi 6 Safety 1190 : 11.9 psi Relief 1103 : 'J psi 1'

10 Relief 1113 i 1. psi 9 Relief 1123 15 psi APPLICABillTY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a. With the safety and/or relief valve function of one or more of the above required safety / relief valves inoperable, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. With one or more safety / relief valves stuck open, provided that suppres-sion pool average water temperature is less than 110 F, take action close the stuck open relief valve (s); if suppression pool average water temperature is 110*F or greater, place the reactor mode switch in the r Shutdown position.

c. With one or more safety / relief tail-pipe pressure switches inoperable, restore the inoperable switch (es) to OPERABLE status within 7 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

d. With either relief valve function pressure actuation trip system "A" or "B" inoperable, restore the inoperable trip system to OPERABLE status within 7 days; otherwise be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

-SURVElLLANCE REQUIREMENTS 4.4.2.1.1 The tail-pipe pressure switch for each safety / relief valve shall be demonstrated OPEPABLE** with the setpoint verified to be 30 t 5 psig by I performance of a:

The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.

initial opening of IB21-F051B is 1103 15 psig due to low-low set function.

- A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in a tripped condition.

GRAND GULF-UNIT 1 3/4 4-5 Amendment No. 20,

Attachment.4-to GNRO-92/00099 i Page 18 of 28

' REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS-(Continued).

a. CHANNEL FUNCTIONAL . TEST at least once per 92 days, and a l 1

b. CHANNEL CAllBRATION at'least once per 18 months.*

4.4.2.1.2 -The relief valve function pressure actuation instrumentation shall be demonstrated OPERABLE ** by performance of a: I

a. CHANNEL- FUNCTIONAL TEST, including calibration of the trip unit, at least once per 92 days. I

b. CHANNEL CAllBRATION, LOGIC SYSTEM FUNCTIONAL TEST and simulated -

automatic operation of the entire system at least once per 18 months.

The provisions lof Specification 4.0.4 are not. applicable provided the surveillance is performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure is adequate'to perform the test.

- A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in a tripped condition.

GRAND GULF-UNIT 1 3/4 4-6 Amendment No. l

.4.

REACTOR COOLANT-SYSTEM-Attachment 4 to GNRO-92/00099 Page 19 of 38 SAFETY /REllEF VALVES LOW-LOW SET FUNCTION LlHITING CONDITION FOR.0PERATION ,

3.4'.2.2 The relief valve function and the-low-low set function of the following reactor coolant system safety / relief valves shall be OPERABLE with the following low-low set function lift settings:

Setpoint* fosio) i 15 osi Valve No. Onen Clqig-F0510 1033 926 F0518 1073 936 F0470 1113 946 F047G 1113 946 F051A 1113 946 F051F 1113 946 APPLICABillTY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

-a. With the relief valve function and/or the low-low set function of one of the above required reactor coolant system safety / relief valves inoperable, restore the inoperable relief valve function and the low-low set functio'n to OPERABLE status within 14 days or be in at least H0T SHUTDOWN within the'next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. With the relief valve function and/or the low-low set function-of more than one of the above required reactor coolant system safety / relief valves inoperable, be in at least HOT-SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the.next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

c. With either relief valve / low-low set function pressure actuation trip system "A" or "B" inoperable, restore the inoperable trip system to OPERABLE status within 7 days; otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS' 4.4.2.2.1 The relief valve function and the low-low set function pressure actuation instrumentation shall be demonstrated OPERABLE ** by performance of a: l-

.a. CHANNEL FUNCTIONAL TEST, including calibration of the trip unit, at least once-per 92 days. l b.-CHANNEL CALIBRATION, LOGIC SYSTEM FUNCTIONAL TEST and simulated automatic operation of-the entire system at least once per 18 months.

The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.

- A channel may be placed _in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in a tripped condition.

GRAND: GULF-UNIT:1 3/4-4-7 Amendment No. __ l

00099 EMERGENCY CORE C00U NG SYSTEMS [a9 2 o 8

-LIMITING CONDITION FOR OPERATION'(Continued) _ -_

ACTION: (Continued)

. c. With one suppression ')ool water level instrumentation division ino>erable, restore tie. inoperable division to OPERABLE status wit 11n-7 days- or verify the suppression pool water level to be greater than or equal to 18'4-1/12" or 12'8", as applicable, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by an alternate indicator,

d. With both suppression pool water level instrumentation divisions inoperable, restore at least one inoperable division to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and verify the suppression pool water level to be greater than or equal to 18'4-1/12" or 12'8", as applicable, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by at least one alternate indicator.

SURVEILLANCE REQUIREMENTS 4.5.3.1 The-suppression pool shall be determined OPERABLE by verifying:

a. The water level to be greater than or equal to, as applicable:

1. 18'4-1/12" at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2.12'8" at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

b. Two suppression pool water level instrumentation divisions, with I channel per division, OPERABLE with the low water level alarm-setpoint 2: 18'5s" by performance of a: 1

1. CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

2. CHANNEL FUNCTIONAL TEST at least once per 31 days, and

3. CHANNEL CAllBRATION at least once per 18 months.

c. Two suppression pool water level instrumentation divisions, with I channel per division, ~0PERABLE" with the low water level alarm setpoint 112. 8" per performance of at

1. CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

2. CHANNEL FUNCTIONAL TEST at least once per 92 days, and

3. CHANNEL CAllBRATION at least once per 18 months.

A channel may be placed in an inoperable status for up to 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months s- during periods of-required surveillance provided at least one other OPERABLE channel in the same system is monitoring that parameter.

GRAND GULF-UNIT 1. 3/4 5-9 Amendment No. 69,

pi t - .

Attachment 4 to GNRO-92/00099' Page 21 of 28 DiERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (continued) 4.5.3.2 With the= suppression pool level less than the above limit or drained in OPERA 110NAL CONDITION 4 or 5*, at least once per 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s:

a. Verify the required conditions of Specification 3.5.3.b to be satisfied, or

b. Verify footnote. conditions

to be satisfied.

G GRAND GULF-UNIT 1 3/4 5-10 Amendment No.

o-

Attachment 4 to GNRO-92/00099 i

Pago 22 of 28 INSTRUtiDRATION BASES . ,

REC 1RCVEATION PUMP TRIP ACTUATION INSTRUMENTAT10N (Continued)

Each EOC-RPT system may be manually bypassed by use of a keyswitch which is administratively controlled, The manual bypasses and the automatic Operating Bypass at less than 40% of RATED THERMAL POWER are annunciated in the control room. The automatic bypass setpoint is feedwater temperature dependent due to the subcooling changes that affect the turbine first-stage pressure-reactor power relationship. For RATED lHERMAL POWER operation with feedwater tempera-ture greater than or equal to 420 F, an allowable setpoint of 5 26.9% of control valve wide open turbine first-stage pressure is provided for the bypass func-tion. This setpoint is also applicable to operation at less than RATED THERMAL The allowable set-POWER with the correspondingly lower feedwater temperature.

point is reduced to s 22.5% of control valve wide open turbine first-stage pres-sure for RATED THERMAL POWER operation with a feedwater temperature between 370 F and 420 F. Similarly, _ the reduced setpoint is applicable to operation at less than RATED THERMAL POWER with the corresponding lower feedwater temperature.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-Of-Service Times for Selected Instrumentation Technical Specifications", February 1991.

The EOC-RPT system response time is the time assumed in the analysis between initiation of valve motion and complete suppression of the electric arc, i.e., 190 ms. Included in this time are: the response time of the sensor, the response time of the system logic and the breaker interruption time. Breaker interruption time includes both breaker response time and the manufacturer's design arc suppression time of 12 ms.

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater then the drift allowance assumed for each trip in the safety analyses.

3/4.3.5 REACTOR CORE ISOLATION COOL _JNG SYSI G ACTUATION INSTRUMENTATION The reactor core isolation cooling system actuation instrumentation is provided to initiate actions to assure adequate core cooling in the event of reactor isolation from its primary heat sink and the loss of feedwater flow to the reactor vessel without providing actuation of any of the emergency core cooling equipment.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06-2, " Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications", February 1991.

GRAND GULF-UNIT 1 B 3/4 3-3a Amendment No. 41, 97, j

{

Attachment 4 to GNRO-92/00099 Page 23 of 28 INSTRUMENTATION-BASES-3/4.3;5; REACTOR CORE IS0lATION COOLING SYSTEM ACTUA110N INSTRUMENTATION (Continued)

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

3/4.3.6 CONTROL-ROD BLOCK INSTRUMENTATION The control rod block functions are provided consistent with the requirements of the specifications in Section 3/4.1.4, Control Rod Program Controls and Section 3/4.2 Power Distribution Limits. The trip logic is arranged so that a trip .in any one of the inputs will~ results in a control rod block.

The OPERABillTY of the control rod block instrumentation in OPERATIONAL CONDITION 5 is to provide diversity of rod block protection to the one rod-out interlock.

Specified surveillance-intervals have been determined in accordance with NEDC-30851P-A, Supplement 1, " Technical Specification Improvement Analysis for

-BWR Control Rod Block Instrumentation" as approved by the NRC and documented in the NRC Safety Evaluation Report (letter to D. N. Grace from C. E. Rossi dated September 22,_1988), Specified surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications", February 1991.-

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

GRAND GULF-UNIT 1 B 3/4 3-3b Amendment No.

. .~ -- -. . _ _ . - - .- _-

' Attachment 4 to GNRO-93/00099 Page 24 of 28 INSTRUMENTATION-BASES

-l 3/4.3.7 - MONITORULG INSTRUMENTAT103 3/4.3.7.1 RADIATION MONITORING INSTRUMENTATIOJ The OPERABILITY of-the radiation monitoring instrumentation ensures that:

(1) the radiation levels are continually measured in the areas served by the individual channels; (2) the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded; and (3) sufficient information is available on selected plant parameters to monitor and assess these variables following an accident. This capability is consistent with the recommendations of NUREG-0737, " Clarification of TMI Action Plan Re. ;irements," November,1980.

Specified surveillance' intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications",

February 1991.

3/4.3.7.2 SEISMIC MONITORING INSTRUMENTATION The OPERABILITY of the seismic monitoring instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic ever- and evaluate the response of those features important to safety.

This capability is required to permit comparison of the measured response to that used in ',he design basis for the unit.

3/4.3.7.3 METEOROLOGICAL MONITORING INSTRUMENTATION The OPERABILITY of the meteorological monitoring instrumentation ensures that sufficient meteorological data are available for' estimating potential radiation doses to the'public as a result of routine or accidental release of radioactive materials. to the atmosphere. This capability is required to-evaluate the need for initiating protective measures to protect the health and safety of the

=public. ~This instrumentation is consistent with the recommendations of Regulatory Guide 1.23 "0nsite Meteorological' Programs," February,1972.

3/4.3.7.4 REMOTE SHUTDOWN SYSTEM INSIRUMENTATION AND CONTROLS

-The OPERABILITY of the remote shutdown system instrumentation and controls ensures that ' sufficient capability is available to permit shutdown and main-tenance of HOT SHUTDOWN of the unit from locations outside of the control room.

-This capability is required in the event control room habitability is lost and

'is consistent with General Design Criterion 19 of 10 CFR 50.

GRAND GULF-UNIT 1 B 3/4 3-4 Amendment No. 41, 97, l

Attachment 4'to GNRO-92/00099.

Page 25 of 28 INSTRUMENTATION BASES 3/4.3.7.10 LOOSE-PART-DETECTION SYSTES The OPERABILITY of the loose-part detection system ensures that sufficient capability is available to detect loose metallic parts in the primary system

" and avoid or mitigate damage to primary system components. The system consists of 16. sensors, of which only 8 are selected and need to be 0PERABLE at a time, to provide the inputs to the 8 monitoring channels. The remaining 8 sensors may be used as replacement sensor inputs for failed sensors or to provide a change in location of the area being monitored. The allowable out-of-service times and surveillance requirements are consistent with the recommendations of Regulatory Guide 1.133, " Loose-Part Detection Program for the Primary System of Light-Water-Cooled Reactors," May 1981.

3/4.3.7 12 1 MAIN CONDENSER OffGAS TREATMENT SYSTEM - EXPLQSIVE GAS MONITORELQ SlSJJM INSTRUMENTATION The explosive gas monitoring systein instrumentation of the main condenser '

off-gas treatment system is provided to monitor the concentrations of potentially explosive gas mixtures in the main condenser offgas treatment systemi This instrumentation is calibrated in accordance with plant procedures.

3/4.3.8 PLANT SYSTEMS ACTUATION INSTRUMENTATLO3 The plant systems actuation'instrum'entation is provided to initiate action to mitigate the consequences of accidents that are beyond the ability of the-operator to control. The LPCI mode of the RHR system is automatically initiated on a high drywell pressure signal and/or a low reactor water level, level 1, signal. The containment spray system will then actuate automatically following

.high drywell and high containment pressure signals. Negative barometric pres-sure fluctuations are accounted for in the trip setpoints and allowable values specified for drywell and containment pressure-high. A 10-minute minimum, 13-minute maximum time delay exists between initiation of LPCI and containment

, spray actuation. A high reactor water level, level. 8, signal will actuate the feedwater system / main turbine trip system. The suppression pool makeup system is automatically initiated on a low low suppression pool water level signal with a concurrent LOCA-signal or following a specified time' delay after receipt of a LOCA signal. The low low' suppression pool water level Trip Setpoint and

- Allowable Value are relative to the surface floor of the suppression pool (93Os" above mean seal level).

Specified surveillance intervals and surveillance and maintenance outage times have been. determined in accordance with General Electri: Report GENE-770-

. 06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-Of-Service Times for Selected Instrumentation Technical Specifications", February

-1991.

GRAND GULF-UNIT 1 B 3/4 3-6 Amendment No. 60, 87, l

s .

REACTOR C0 PLANT SYSTfM Atta hment 4 to GNRO-92/00099 Page 26 of 28 BASES

~ _

3/4.4.2- SAFETY /REllEF VALVES-The safety valve function of the safety / relief valves (SRV) operate to prevent the reactor coolant system from being pressurized above the Safety

-Limit of 1325 psig in accordance with the ASME Code. A total of 13 OPERABLE safety / relief valves is required to limit reactor pressure to within ASME Ill allowable values for the worst case upset transient. Any combination of 6 SRVs operating in the relief mode and 7 SRVs operating in the safety mode is acceptable.

Demonstration of the safety / relief valve lift settings will occur only during shutdown-and will be performed in accordance with the provisions of Specification 4.0.5.

.The low-low set system ensures that safety / relief valve discharges are minimized for a second opening of these valves, following any overpressure transient. This is achieved by-automatically lowering the closing setpoint of 6 valves and lowering the opening setpoint of 2 valves following the initial opening. In this way, the frequency and magnitude of the containment blowdown duty cycle is substantially reduced. Sufficient redundancy is provided for

.the low-low set system such that failure of any one valve to open or close at its reduced setpoint does not violate the design basis.

Specified surveillance intervals and surveillance outage times have been

- determined in accordance with General Electric Report GENE-770-06-1, " Bases

-for Changes lto Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications", February 1991.

3/4.4.3 REACTOR COOLANT SYSTEM LEAKAG_f 3/4.4.3.1 LfAKAGE DETECLION SYSTEMS

.The.RCS leakage detection systems required by this specification are

-provided to monitor and. detect leakage from the reactor coolant pressure boundary.. These systems provide the ability to measure leakage from fluid systems in the drywell.

3/4.4.3.2 OPERATIONAL LEAKAGE The allowable leakage rates from the reactor coolant system have been based on the predicted and experimentally observed behavior of cracks in pipes. The normally expected background leakage due to equipment design and the detection capability of the' instrumentation for determining system leakage was also considered. The evidence obtained from experiments suggests that for leakage somewhat greater than that specified for UNIDENTIFIED LEAKAGE the probability- )

is small that the imperfection or crack associated-with .such leakage would ;

grow rapidly. However, in all cases, if the leakage rates exceed the values l specified or the leakage is located and known to-be PRESSURE BOUNDARY LEAKAGE, I the reactor will be shut down to allow further investigation and corrective- l action. Service . sensitive reactor coolant system Type 304 and 316 austenitic l stainless steel piping, i.e., those that are subject to high stress or that contain relatively stagnant, intermittent, or low flow fluids, requires additional surveillance and. leakage limits.

GRAND GULF-UNIT I B 3/4 4-2 Amendment No.

l

Attachment 4 "r; GeiRO-92/00099 Page 27 of -

f((AGDR_LQQLA!11_1Y11[3 BASES --

- .. .a.===-

w. _.

3/_42 42 2 OPERATIONAL LEAKAG1 (continued)

The Surveillance Requirements for RCS pressure isolat - . !'vos provide added assurance of valve integrity, thereby reducing the !.:ility of gross valve failure and consequent intersystem LOCA. Leakage '~ ne RCS pressure

" . as a portion of isolation valves is IDENTlflED LEAKAGE and will be cons :

the allowed limit.

O _

g GRAND GULF-UNIT 1 B 3/4 4-2a Amendment No. _

Attachment 4 to GilRO-92/00099 '

Page-28 of 28 3

3/4.5 ~ EMERGENCY CORE COOLING SYSTEB BASES SUPPRESS 10ltfa91 (Continued)

In OPERA '0NAL CONDITION 4 and 5'the suppression chamber minimum required water volume is reduced because the reactor coolant is maintained at or below 200* F . Since' pressure su)pression is not required below 212*F, the minimum required water volume is )ased on NPSH, recirculation volume, and vortex prevention _plus a l'2" safety margin for conservatism.

Specified surveillance intervals and surveillance outaae times for the wide range suppression pool water level instrumentation have been determined in accordance with General Electric Report GENE-770-06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications", February 1991.

GRAND GULF-UNIT 1 B 3/4 5-2 Amendment No.

.n.

e Attachment 5 to GNRO 92/00099 Page 1 of 3 l

l l

1 I

GGNS Trip Unit Drift Data in Support of PCOL-92/03 f.

j ';

o .

m ._ - . . . . . _

F.

g Attachment 5 to GNRO-92/00099 Page 2 of 3

' GGNS Trio Unit Drift Data in Sucoort of PCOL-92/03 Drift studies were performed in support of the TS changes proposed in Attachment 2 of this submittal. Only instrumentation channels with current monthly calibration requirements were examined.

These studies used the same methodology as that used previously to support the RPS TS changes approved for GGNS by the NRC in Amendment No. 67. Approximately ten percent of a given type of channel were examined on a random basis (e.g., ten percent of RCIC actuation instrumentation channels required by TS were examined). Table 1 presents a summary of the instrumentation examined.

A review of surveillance ' data sheets was performed for each of the selected channels to determine how much the trip unit setting changed from the beginning to the end of three consecutive surveillance intervals. The results are tabulated in attached Table 1, and compared against the allowable trip unit drift for a 92 day period, as determined by using the GE setpoint methodology described in NEDC-31336.

If all of the change in trip unit trip setting observed in the surveillance data of Table 1 is conservatively attributed to drift, the worst case actual drift experienced in the plant remains less than the amount of drift assumed for trip units in the setpoint methodology.

Therefore, based on the above, no safety concern exists due to extending the calibration frequency from 31 to 92 days because the drift experienced in the field is much less than the drift allowed for in the setpoint methodology. The calibration frequency extensions will not significantly reduce the likelihood of a needed trip occurring when required due to excessive trip unit drift and confirms the conclusions reached in the GE Topical Reports.

l l

Table 1 GGNS TRIP UNIT DRIFT DATA Applicable Trip Unit Number Descriptior, Net Change Allowed Drift Model Tech Spec (3 months) s.. mmququmummemumpmmu Endef-Cycle RPT Q1C71NE06F Turbine Stop Valve Closure, Ch. F -0.01mAdc 10.02 madc Rosemount 510 DU237030 RCic Q1821N6928 RPV Water Level 2. Ch. B O.00 mA 10.02 mA Rosemount 510-DU7

,lRV Relief Q1821N670E Reactor Vessel Pressure Ch. E 4.01 mA 10.02 mA Rosemount 510-DU7 yg SRV Relief o-Q1821N668E Reactor Vessel Pressure, Ch. E + 0.01 mA 2 0.02 mA Rosemount *$

5104U2 [3 SRV-Lo-Lo-Set Q1821N6188 Reactor Vessel Pressure, Ch. B + 0.01 mA 10.02 mA Rosemount G3 510-DU7 $

o Containment Spray Q1821N691A RPV Water Level 1 Ch. A O.00 mA 10.02 mA Rosemount O 510-DU2 $

Suppressxm Pool Q1C71N6500 Drywell High Pressure, Ch. D -0.01 mA O 10.02 mA Rosemount 6 Make4fp 510-DU2 t' o

Suppression Pool Q1821N682A Make-Up RPV Water Level 2 Ch. A 2 0.01 mA 20.02 mA Rosemount 8 510DU7 E Suppression Pool Q1E3ON6008 Suppression Pool Water Level, Ch. B O.00 mA 10.02 mA Rosemount Make-Up 5100U246012

. _ _ _ ___________ _____. . .x

ML20113H603

Text

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