Text

Proposed Tech Specs Re Alternate DHR & LPCI Manual Realignment
	ML20056A820
Person / Time
Site:	Grand Gulf
Issue date:	08/06/1990
From:	; ENTERGY OPERATIONS, INC.
To:	;
Shared Package
ML20056A819	List: AECM-90-0135, Application for Amend to License NPF-29,revising 900427 & 0705 Applications Re Changes to Tech Spec Due to Addition of Alternate DHR & Addressing NRC Concerns Re Manual Realignment of LPCI Emergency Core Cooling Subsystems; ML20056A820;
References
	NUDOCS 9008090245
	Download: ML20056A820 (25)
	v • d • e

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-20 c3 g-g yo z TABLE 3.3.2-1 (Cartinued)

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t1o C ISOLATION ACTUATI0t! IN51RLSENTATION r--

Ka -

E VALVE GROUPS MINIMl01 APPLICABLE .

-- O. 1 OPERABLE CHAf8ELS . OPERATIONAL ~ -l

,y T OPERATED BY ACT10N ;

Go oo @ -

TRIP FUNCTION SIGNAL (a) PER TRIP SYSTEN (b) C00RilTION: -

y- i m8$

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" 5. REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION C'$ 1. RHR Equipment Room Ambient

~

Temperature - High 4 1/ roes 1, 2, 3 27

j. RHR Equipment Room a Temp. -

High 4 1/ rose 1, 2, 3 27

k. IIHR/RCIC Steam Line Flee -

-High 4 1 1, 2, - 3 27 1,2,3 26- 1

1. Manual Initiation' ' 4 III 1 w

A e. Drywell Pressure-High 9I *I- 1 1,2,3 27. l^

w (ECCS-Division 1 and 4 Division 2) w

6. RHR SYSTEM ISOLATION 'l

a. RHR Equipment Rose Ambient ~

Temperature - High .3 1/ room 1, 2, 3 28 -

l

b. RHR Equipment Room A Temp. - High 3 1/ room 1, 2, 3 28

( c. Reactor Vessel idater 2 1, 2, 3 28 g Level - Low, Level 3 -

(P) (p) 'ag,g

' 3 }TJ.

h

d. Reactor Vessel (RHR Cut-in

-t- Permissire) Pressure - gj)

High 3 2 1,2,3 28 7

. e. Drywell Pressure - High 3 I} 2 1,2,3 28

f. Manual Initiation 3 2 1,2,3 76

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.. INSTRUMENTATION--

TABLE 3.3.2-1 (Continued).

ISOLATION ACTUATION INSTRUMENTATION ACTION 3

ACTION 20 -

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 . l ACTION 21- - Close the affected system isolation valve (s) within one hour. or:

a.- _In OPERATIONAL CONDITION 1, 2, or 3, be in at least HOT i 4

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. In OPERATIONAL: CONDITION *, suspend CORE ALTERATIONS;

)

handling of irradiated fuel f r; the primary containment and ,

operations with a-potential ter dr-ira.9 the reactor vessel.

ACTION 22 - Restore'the_ manual initiation function to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT SHUT 00WN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months i

!, and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 23 -

Be~in at least STARTUP with the associated isolation valves closed )

within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months j and in COLD SHUTOOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 24 -

Be in at least.STARTUP within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , u, . ACTION 25 -

Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas t,

treatment system operating within one hour.

ACTION 26 -

Restore the manual initiation function to OPERABLE status

j. within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or close the affected system isolation valves within the next hour and declare the affected system inoperable.

ACTION 27 -

Close the affected system isolation valves within one hour and declare the affected system-inoperable.

ACTION 28 -

With_in one hour lock the affected system isolation valves closed, or verify, by remote indication, that the valve is closed and i

electrically disarmed, or isolate the penetration (s) and declare i-the.affected system inoperable.

[ Close the affected system isolation valves within one hour and ACTION 29 -

i

'. declare the affected system or component inoperable 'or:

a. In 0PERATIONAL CONDITION 1, 2 or 3 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 SHOTDOWN within the L gg following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . '

p b. In OPERATIONAL CONDITION # suspend CORE ALTERATIONS and opera- .

tions with a potential for draining the reactor vessel.

ACTMN 30 -

Declare the affected SLCS pump inoperable.

' ]

l NOTES l

When handling irradiated fuel in the primary or secondary containment and i- during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.

The low condenser vacuum MSIV closure may be manually bypassed during reactor

. SHUTDOWN or for reactor STARTUP when condenser vacuum is below the trip set-point to allow opening of the MSIVs. The manual bypass shall be removed when l, -condenser vacuum exceeds the trip setpoint.

During CORE ALTERATIONS and operations with a potential for draining the reactor vessel.

1. With any control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

(a) See Specification 3.6.4, Table 3.6.4-1 for valves in each valve group.

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dy ; ACTION 31 - Isolate the shutdown cooling common suction-line within one hour f' ^." if-it is not needed for shutdown cooling or initiate action within~ -

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4 , one hour to establish SECONDARY CONTAINMENT ~ INTEGRITY, k.

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INSTRUMENTATION I

TABLE 3.3.2-1 Continued) i ISOLATTON"KCTUATTUR (INSTRUMENTATION NOTES (Continued) l (b) A channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for required, surveillance without placing the trip system in the tripped con-dition provided at least one other OPERABLE channel in the same trip system is monitoring that parimeter.

(c) Also actuates the standby gas treatment system.

~(d) Also actuates the control room emergency filtration system in the isolation mode of operation.

(e) Two upscale-Hi Hi, one upscale-Hi Hi and one downscale, or two downscale signals from the same' trip system actuate the trip system and initiate -

-isolation of the associated containment and drywell isolation valves.

-(f) Also trips and isolates the mechanical vacum pumps.

(g) Deleted.

(h) Also actuates secondary containment ventilation isolation dampers and- -

valves per Table 3.6.6.2-1. 4 (i) Closes only RWCU system isolation' valves G33-F001, G33-F004, and G33-F251._

(j) Actuates the Standby Gas Treatment System and isolates Auxiliary Building penetration of the ventilation systems within the Auxiliary. Building.

(k) Closes only RCIC outboard valves. A concurrent RCIC initiation signal is

required for isolation to occur.

(1) Valves E12-F037A and E12-F0370 are closed by high-drywell pressure. All -

other Group 3 valves are closed by high reactor pressure. .'

(m) Valve Group 9 requires concurrent drywell high pressure and RCIC Steam.

Supply Pressure-Low signals to isolate.

L (n) Valves E12-F042A and E12-F042B are closed by Containment Spray System- -

initiation signals.

(o) Also isolates valves-E61-F009, E61-F010, E61-F056, and E61-F057'from Valve Group 7.

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> INSERT 2-T0-TS TABLE 3.3.2-1 Page 3/4l 3-15 (p) Only required to isolate RHR-system iselation. valves E12-F008 and J

E12-F009 :One trip system and/or. isolation valve may be inoperable for upito .14 days without placing-the trip' system in the tripped condition-provided'the diesel generator' associated with'the OPERABLE' isolation

valveLis 0PERABLE..

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@ TABLE 4.3.2.1-1 (Continued) 7_g E T*.

ISOLATION ACTUATION INSTRUNENTATION SURVEILLANCE REQUIREMENTS c _

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4 CHANNEL OPERAT10NAL -%

p 2,

CHAleIEL FUNCTIONAL CHANNEL- ColelileNS IN 1AllCh *

-< TRIP IUNCTION CHECK TEST CALIBRATION SURVEILLAleCE REQUIRED -

5. REAC10R CORE ISOLATION COOLIleG "'3 TEM ISOLATION (Continued)

h. Main Steam Line Tunnel Temperature Tleer NA M Q 1, 2, 3

i. RHR Equipment Room Ambient Temperature - High 5 'M A 1, 2, 3

j. RHR Equipment Room a Temp. -

High 5-M A 1, 2, 3

k. RHR/RCIC Steam Line Flow -

High .5 M R(c) 1. 2, 3

1. Manual Initiation MA M(*} NA 1. 2, 3 -

w m. Drywell Pressure-H!gh 5 M R(C} 1, 2, 3 4

m (ECCS Divisfor. I and Division 2)

6. RHR SYSTLM ISOLATION

a. RHR Equipment Room Ambient Temperature - High 5 M A 1, 2, 3

b. RHR Equipment Room A Temp. - High 'S M A 1, 2, 3 D c. Reactor Vessel Water level -

tow, Level 3. 5 M RI '} 1, 2, 3,9,5 25 d. Reactor Vessel (RHR Cut-in Sh- Permissive) Pressure - High 5 M RI '} 1, 2, 3 3

<a h

2.

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m..,-,_m - . . . - - . . _ = . - _ _ _ -_-_c ._ _..~__.- _ _--.~ _ ._ , _ , - - -_ ._-

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_g TABLE 3.3.7.1-1' 5 . RADIATION MONITORING INSTRUNENTATION. 2:.

c) F k NINIMUM CHANNELS APPLICABLE' ALARM / TRIP MEASUREMENT _.b

. INSTRUMENTATION OPERABLE CONDITIONS SETPOINT RANGE ACTION O-E 1. Component Cooling -

p' Q Water Radiatior 5

Monitor 1 At all times il x 10 cpe/NA 10 to 106cpm 70 1

2. Stan4y Service Water .;

System Radiation '

l Monitor 5 1/ heat 1, 2, 3, and* 11 x 10 cpe/NA 10 to M cpm U.

70 exchanger train

3. Plant Service Water w System Radiation '

3 Monitor 1 ## il x 10 cpe/NA5 10 to 106cpm .70

" 3 4 4. [ DELETED]

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5. Carbon Bed Vault '

Radiation Monitor 6 k,E 1 1, 2 < 2 x full power 1 to 10 mR/hr' 72 Eackground/NA

6. Control Room Ventila-f' 2/ trip (h) tion Radiation Monitor system 1,2,3,5 and** 14 mR/tr/ -2 to 102mR/hr 10 -73 ,

_5 mR/hr# -

7. Containment and Drywell Ventilation Exhaust 2/ trip (h)-

h ~I Li Radiation Monitor system At all times <2.0 mR/hr/ 10

-2 to 10 mR/hr 2 74 14 mR/hr(b)#

E 8. Fuel Handling Area

-2 E, Ventilation Exhaust 2/ trip (h) 1,2,3,5 and** $2mR/hrfd)# 10 to.102mR/hr 75

, Radiation Monitor- system 14 mR/hr

? 9. Fuel Handling Area Pool m

Sweep Exhaust Radiation 2/ trip (h) -2 Monitor system tE 102mR/hr

-(c) < 18 mR/hr/ 10 75 h35mR/hr(d)#

- . - . . , . , - . - + . ~ . - , . - .

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p y TABLE 3.3.7.1-1:(Continued) 5 RADIATION MONITORING INSTRUNENTATION E' c) "

E MINIMUN CHANNELS- APPLICABLE ^ ALARM / TRIP MEASUREMENT b INSTRONENTATION OPERABLE CONDITIONS

] SETPOINT RANGE . ACTION.

E 10. Area Monitors- '

Q a. Fuel Handling Area.

s Monitors

1) New Fuel 1 (e) -<2.5 mR/hr/NA 10

-2 to 103mR/hr 72 Storage Vault

-2

2) Spent Fuel 1 (f) ~<2.5 mR/hr/NA 10 to 103mR/hr 72f Storage Pool w 3) Dryer Storage 1 (g) .10 -2 to 133mR/hr # ~

<2.5 mR/hr/MA 72.

1 Area k7 .. '

-2

b. Control Room 1 At all times ~<0.5 mR/hr/NA 10 to 103mR/hr 72 '3 Radiation Monitor ~ 'hj 6'

3 s With RHR heat exchangers in operation.

i

- 'O When irradiated fuel is' being handled in the primary or secondary containment.. 3 Final Setpoint to be detemined during startup test program. Any required change to-

Initial setpoint.

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

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1. With ADHR heat exchangers in operation. I !

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

F (b) Isolates containment /drywell purge penetrations.

$ (c) With irradiated fuel in spent fuel storage pool.

E (d) Also isolates the Auxiliary Building and Fuel Haadling Area Ventilation Systems. *

(e) With fuel'in the new fuel storage vault; (f) With fuel in the spent fuel storage pool..

& (g) With fuel in the dryer storage area.

(h) Two upscale Hi Hi, one upscale Hi Hi and one downscale, or two downscale signals-from the same trip '

E system actuate the trip system and initiate isolation of the associated isolation valves.

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TA8LE 4.3.7.1-1 i o RADIATION MONITORING INSTEREllTATIDiF3DRVEILLANCE REQUIREENTS -

' % ~4

OPERATIONAL ~ E E CHANNEL CONDITIONS FOR: $,

@ -C! e.NEL. -FUNCTIONAL CHANNEL WHICH SURVEILLANCE T-o q;

' 1.

INSTRUMENTATION Component Cooling Water Radiation LHECK TEST CALIBRATION REQUIRED .R.

E Monitor % >

5 A' At all times ,

4 M

p 2. Standby Service Water System Radiation Monitor S M A 1, 2, 3,.and*

3. Plant Service Water System

Radiation Monitor 5 M A #-

, 4. [ DELETED]

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

6. Control Room Ventilation. Radiation i Monitor S M(a) g- 7,.2, 3, 5 and** -

7. Containment and Drywell Ventilation Exhaust Radiation Monitor S M

A At all times'

8. Fuel Handling Area Ventilation 4

't' Radiation Monitor S M A 1, 2, 3, 5 and**

O 9. Fuel. Handling Area Pool Sweep @5 '

Exhaust: Radiation Monitor S~ M- A (b) i

10. Area Monitors >1

a. Fuel Handling. Area Monitors ,

'hd

1) New' Fuel Storage Vault 5: M R (c) 6' -

2) Spent Fwl. Storage Pool 5 M R (d) ; .1 ,

3) Ggar Storage Area .S N R (e)

b. Control Room Radiation Monitor S M -R At all times' 'O< t 7

q With RHR heat exchangers in operation.

.g *(a*) When irradiated fuel is being handled in the primary or secondary containment.

The CHANNEL FUNCTIONAL' TEST shall demonstrate that control- room annunciation occurs if any of .the following j

E conditions exist. -

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

3 2. Circuit failure. '

z 3. Instrument indicates a downscale failure. '

? 4. -Instrument controls not in Operate mode.

m

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

j (c) With fuel in the new fuel storage' vault.

(d) With fuel in the spent fuel. storage pool.

(e) With fuel in the dryer storage area. ,

With ADHR heat exchangers in operation.

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,s REACTOR COOLANT SYSTEM'

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COLD SHUTDOWN-LIMITING CONDITION FOR OPERATION g

3.4.9.2 Two -shutdown cosling!aode loops of the residual heat removal (RHR) system shall;be.0PERABLE3nd, unless at least one recirculation pump is in . li operation, at least one shutdown cooling r. ode loop shall be in operation *'## ]

with each loop consisting.of at least: q

a. One OPERABLE RHR pump, and j

b.- One OPERABLE RHR heat exchanger. 1 APPLICABILITY: OPERATIONAL CONDITION 4.-

ACTION:

a. With less than the above required RHR shutdown cooling mode loops OPERABLE, ;

within one hour and.at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereaf ter, demonstrate .the OPERABILITY of at least one alternate method " capable of decay heat 1

['"3V*I d?[ eac(inoperable RHR shutdown cooling mode loop. 3 g evi;ier.e

" 1. I'" " " ' .' ' ' ' '."" " 1 "12 " ' " "" * " F F ' ' * " ' ' '""*'I '"'"'"""""'

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b. With no RHR shutdown cooling mode loop in operation, within one hour establish reactor' coolant circulation by an alternate method and monitor o reactor coolant temperature and pressure at least once per hour, w '

SURVEILLANCE REQUIREMENTS i1 4.4.9.2 _At least one.shutaown cooling mode loop of the residual heat removal I system or alternate method shall'be determined to be in operation and .!

circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

0ne RHR shutdown cooling mode loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for j surveillance. testing provided the other loop is OPERABLE and in operation.

The shutdown cooling pump may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided the other loop is OPERABLE.

1. The shutdown cooling mode loop may be removed from operation during m.. gdrostatictesting. ,, , ,,, , , , , , , , ,,

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Page 3/4.-. 4 '

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- --' 'One'.of the two shail have an OPERABLE associated diesel generator.

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' EMERGENCY _ CORE COOLING SYSTEMS' 3/4 5.2 ECCS --SHUTOOWN T

LIMITING CONDITION FOR OPERATION 3.5.2 ~At least two of the following shall be OPERABLE a; The low pressure core spray (LPCS) system with a flow path capable of taking suction from the suppression pool and transferring the water-through the spray sparger to the reactor vessel.

b. Low pressure coolant injection (LPCI) subsystem "A" of the RHR system-with a flow path capable of taking suction from the suppression pool ;

-- . b;ing ;;.r.uell> reeligned and transferring the water to the.-

reactor vessel. -[

c._ Lowp*essurecoolantinjection(LPCI) subsystem"B"'oftheRHRsystem-with a: flow path capable of taking suction from the suppression pool

-u;;;n b;ia; .;r..;113 realisi.ed and transferring the water to the. [<;

reactor vessel.

~

d.- Lowpressurecoolant-injection (LPCI) subsystem"C"oftheRHRsystem -

with a flow path capable of taking suction from the suppression pool uven L.inv manuai sy reengnea and transferring the water to .the reactor. vessel. [

e. The high pressure core spray (HPCS) system with a flow path capable-of taking suction from one of the following water sources and trans-ferring-the water through the spray sparger to the reactor vessel: '

1. From the suppression pool, or W"en the suppression pool ?evel is less than the -limit or is

2. i drained, from the condensate storage tank containing at least 170,000 available gallons of water, equivalent to a level of 1

,. 18 feet.

APPLICABILITY: OPERATIONAL CONDITION 4 and S*.

ACTION!

1.PMERT usou ___au. _ < _ . . . ___..,__2 ...m....___i_....__._ ,______u. ___.___ i

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b. With both of the above required subsystems / systems inoperable, suspend CORE ALTERATIONS and all operations that have a potential for draining the reactor vessel-._ Restore at least one subsystem / system to OPERA 8LE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or establish SECONDARY CONTAINMENT INTEGRITY within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

M The ECCS is not required to be OPERABLE provided that the reactor vessel head is removed, the cavity is flooded, the reactor cavity and transfer canal gates

in the upper containment pool are removed, and water level is maintained 1

'within the limits of Specifications 3.9.8 and 3.9.9.

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sy "" a .With one_of the above required subsyst' ems / systems inoperable, provided an

! automatic 1 subsystem / system is OPERABLEJ restore at least two .

subsystems / systems to.0PERABLE~ status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or suspend all operativa s .

that- have a potential for draining the 1 reactor vessel. . 'Otherwise, with'no !

automaticLsubsystem/ system OPERABLE, suspend all. operations that have a; '

1 potentialJfor draining the. reactor vessel. ,

q INSERT 2 TO TS 3/4.5.2

p #;- One of the two required 'ECCS- subiystems/ systems may require manual i realignment prior to initiation and: injection.

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}' '[ CONTAINMENT SYSTEMS-g 3/4.6.4 CONTAINMENT AND ORYWELL ISOLATION VALVES-JLIMITING CONDITION FOR'0PERATION 3.6.4' The containment and drywell isolation valves shown in Table 3.6,4-1

-shall be OPERABLE with isolation times less than or equal to-those shown in Table-3.6.4-1.-

i APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, and.#.

+ ACTION:'

With one or more of the containment or drywell isolation valves sho' wn in Table 3.6.4-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either:

a.

i Restore the inoperable valve (s) to OPERABLE status, or l l'

b.. Isolate each affected penetration by use of at least one deactivated automatic valve secured in the isolated position,* (tt, pre.i;ie,,; ef S;::'"h:ti= 3. 0. ' r: ::t ;;1t =t h ':r ::try 'nt: =ndith f

=i tr :" '.0 inpr;th n:t: inn t nd dry ;il i;;Mtin

= h n**), or '

c. Isolate each affected penetration by use of at least one closed manualvalveorblindflangg(tt.; pre.i;in;of0;nif;;; tin 3.0. " r; nt ;;;linth f;. .r.tr3 int; ;r.ditka fer ; n,,i;n

' '0 i ng s ;t'; n at: .ir.n t at drf ;il i.e'etiv, ..i..,**). i s

Otherwise, 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 -!

C0iD SHUTDOWN within the fo11owing 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . "

l (

l f

Isolation valves, except MSIVs, closed to satisfy these requirements may be reopened on an intermittent basis under administrative controlsg(07"MTICA 00"0!T!0" :P.r.;n r nt diknd d'h Schti:n ::!=: r ;;r :dr 1b.=:

ce'- S tr:tf= :::tr: h**).

Isolation valves shown in Table 3.6.4-1 are also required to be OPERABLE when their associated actuation instrumentation is required to be OPERABLE per Table 3.3.2-1.

- ?h :=:;t!= h :;;1h:th :ti' :trte; 'r:: th: th'rd 7 '= ling :;t ;;.

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GRAND GULF-UNIT 1 3/4 6-28 Amendment No. 58,_

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Page 3/4 6-28

- >ExceptlforE12-r008andE12-F009in-OPERATIONALCONDITIONS4and5tak'e-

' action per, Specification 3.3.2, Table 3.3.2-1, Trip Function 6.c.

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TABLE 3.8.4.2-1 (Continued)- ,

MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION

. BYPASS DEVICE (CON-TINU005)-(ACCIDENT SYSTEH(S) .

VALVE NUMBER CONDITIONS) (NO)~ AFFECTED t

-Q1E12F074A Co'ntinuous RHR System Q1E12F026A Continuous RHR System Q1E12F082A No RHR System Q1E12F082B No RHR System Q1E12F290A Continuous RHR System Q1E12F047A- Continuous RHR System Q1E12F027A Continuous 'RHR System i Q1E12F073A Continuous RHR System Q1E12F346 Continuous RHR System -

'Q1212F024A Continuous RHR System !

Q1E12F087A Continuous RHR System 4 Q1E12F048A Continuous RHR System Q1E12F042A Continuous RHR System "

Q1E12F004A Continuous RHR System Q1E12F003A Continuous RHR System -

Q1E12F011A Continuous RHR System Q1E12F053A' Continuous RHR System Q1E12F037A Continuous -RHR System Q1E12F028A Continuous RHR System Q1E12F064A Continuous RHR System Q1E12F066A Continuous. RHR System l Q1E12F290B' Continuous RHR System ,

Q1E12F004C Continuous RHR System Q1E12F021 Continuous RHR System Q1E12F064C Continuous- -RHR. System Q1E12F042C Continuous RHR System Q1E12F048B Continuous- RHR System 1 Q1E12F049 Continuous RHR System Q1E12F0378 Continuous RHR System Q1E12F053B Continuous RHR System Q1E12F0748 Continuous -RHR System Q1E12F042B Continuous RHR System Q1E12F0648 Continuous RHR System

- Q1E12F096 Continuous RHR System Q1E12F094 Continuous RHR System Q1E12F006B Continuous RHR System Q1E12F011B Continuous RHR System Q1E12F052B Continuous RHR System Q1E12F0478 Continuous RHR System Q1E12F027B Continuous RHR System Q1E12F004B Continuous RHR System Q1E12F0878 Continuous RHR System Q1E12F003B Continuous RHR System }

Q1E12F026B Continuous RHR System Q1E12F0248- Continuous RHR System Q1E12F0288 Continuous RHR System Q1E12F009 Continuous RHR System Q1E12F073B Continuous RHR System Q1E12F066B Continuous RHR System (

GRAND GULF-UNIT 1 3/4 8-48 Amendment No.59

7

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REFUELING ~ OPERATIONS- ,

b -

, 3/4.9.11 RESIDUAL NEAT REMOVAL AND COOLANT CIRCULATIG4 o

(

m HIGH WATER-LEVEL k.3 i{ ' , LIMITING CONDITION FOR OPERATION -

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-3.9.11.1r ^.t i n :t n: ;h;tt:= :nlia; nd; tr;in ;f tb ruidni hnt r;nni '

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("ll") ;y;t r ;bli h 0^ "'."LE nd in :;;r:.ti n* .ith :t h u t;

s. One OPEa' ELE ^::a p ,,, and

b. One.0," "",0L "':" h a t n;h ng;r tr;ia.-

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APPLICABILITY: OPERATIONAL CONDITION 5, when irradiated fuel is in the reactor' vessel and the water level is greater than or e i the top of. the reactor' pressure vessel flange. qual to 22 feet 8 inches above-

' ACTION: 1 a.- With no RHR shutdown cooling mode train OPERABLE within one hour and at least-once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter, demonstrate the OPERABILITY of at least.-

one alternate method M apable of decay heat removal. Otherwise, suspend I; all operations involving an increase in the reactor decay heat load'and '

establish SECONDARY CONTAINMENT INTEGRITY within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , b.. With no RHR shutdown cooling mode train in operation, within one hour establish reactor coolant circulation by an alternate method and monitor reactor coolant temperature at least once per hour.

. h: pr=i i:= Of Senifintin 3.0.t ;r; net ;ppli;; tie.# l SURVEILLANCE REQUIREMENTS 4.9.11.1 At.least one shutdown cooling mode-train of the residual heat removal systenuor alternate method shall.be verified to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . -l: !

DHh

The shutdown cooling pump,may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per l 8-hour. period.

This nuptien i; ;ppiinti; ;atil ;t;rtup fra th; :nnd r;f;; iia; :st;;;.

- Tlm elte,nate dec;j heet con ni ;y;t s (^.0""0) => b; ;;;d = th: :lte rate d; na h n t ru n :1 = th d f;r th: tMM r: fueling =t:g: :r ?) .

MEAT A3 GRAND GULF-UNIT 1 3/4 9-18 Amendment No/38, 53-

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.Page 3/4 9-18 ,

1 One of two of the folle ring shall be OPERABLE # and, unless the' alternate 1

. decay heatjremoval system is in operation, at least.one of the following two:

.shall be.in operation *: '

ca. residual-h' eat removal (RHR)-system shutdown cooling. mode train "A", or-y, l 'b. RHR system. shutdown cooling mode train "B".

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.i INSERT 2 TO TS 3L4.9.11.1

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J/L '; #' The'one required shall have an OPERABLE associated diesel generator.

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APPLICA8ILITY: OPERATIONAL CONDITION 5, when irradiated fuel is in the reactor vessel and the water level is less than 22 feet 8 inches above the-top of the reactor pressure vessel flange. ;

n L ACTION:

hMEAT A

a. With less.than the above required shutdown cooling mode trains of the RHR - 4 system OPERA 8LE, within one hour and at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereaf ter, demonstrate the OPERA 8ILITi of at least one alternate method **'" capable of decay heat removal for each inoperable RHR shutdowa cooling mode train.4 -

b. With no= RHR shutdown cooling mode train in operation, within one hour

- establish reactor coolant circulation by an alternate method and monitor-reactor coolant temperature at least once per hour.

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$5tE i'.i SURVEILLANCE REQUIREMENTS 4.9.11.2 At least one shutdown cooling mode train of the residual heat removal systemer alternate method shall be verified to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . '

e_ = . =-

, ADHR5inthe readereoolig m.hd i

,= - -- ;

or AbHRS '

M The shutdown cooling p . may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months l per 8-hour period.

Th!, m . 6 l . le .,,,,,licatie r.tfi ; tert.; fr;: th; th'rd reft:""; OW; .

- Th. elt.,oute doce, heet .. ;,.e ;j;t;; ) ;;, b; .;d ;; th; ^1 t Tr.;t;

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" INS Ea'r GRAND GULF-UNIT 1 3/4 9-19 Amendment No/JA 59;-

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Page 3/4 '9-19:

Two of three'of the following shall be'0PERABLE # a' at least one sha'ii- ve in <

y , operation *:- !

a-. residual heat removal (RHR) system shutdown cooling mode train "A", or.

. b. RHR. system shutdown cooling mode train "B", or k c. alte'rnate decay heat-removal system (ADHRS) in the reactor cooling mode.

L

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INSERT 2 T0 TS 3L4.9.11.2 Page 3/4 .9-19

$1 .

Otherwise, either raise water level to greater than orfequal. to 22 ' feet 8 inches above the top of the reactor pressure vessel- flange within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .of

~

a,;: discovery of the inoperable system or alternate or suspend all operations' involving an increase in the reactor decay heat load and initiate action t within one hour to establish SECONDARY CONTAINMENT INTEGRITY.

9 g.

's INSERT 3 TO TS 3/4.9.11.2 Page 3/4 9-19 ,

I

One of the two required shall have an OPERABLE associated diesel generator. ',

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A9007231/SNLICFLR - 36

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l'S ' 3/4.5 EMERGENCY CORE COOLING SYSTEM

~

BASE 5 l

-ECCS-OPERATING and SHUT 00WN (Continued).

.The capacity of the system is selected to provide the required core cooling.

The HPCS pump is-designed to deliver greater than or equal.to 1650/7115Lgpm at differential pressures of 1147/200 psid. Initially, water from the condensate storageftank'is used instead of. injecting water from the suppression pool-into..the: reactor, but no credit is taken in the safety analyses for the=

condensate storage tank ~ water. ,

With- the.HPCS system inoperable, adequate core cooling is assured by the OPERABILITY of the redundant and diversified automatic depressurization system and both the LPCS and LPCI systems. In addition,.the reactor core isolation '

cooling (RCIC) system,~a system for which no credit is taken in the safety analysis, will automatically provide makeup at reactor operating _ pressures )

.on a reactor low water level condition. The HPCS out-of-service period of l 14 days is based on the' demonstrated OPERABILITY of redundant and diversified low pressure core cooling systems.

The surveillance requirements provide adequate assurance that'the HPCS system;will-be OPERABLE when required. Flow and total developed head values for surveillance testing include system losses to ensure design requirements

~

are met, i Although all active components are testable and full flow can be.

demonstrated by recirculation through a test loop during reactor operation, a complete-functional test with reactor vessel injection requires reactor shutdown. '

The pump discharge piping is maintained full to prevent water hammer damage 'and to provide cooling at the earliest moment,

,Upon failure of the HPCS system to function properly after a small break loss-of-coolant accident, the automatic depress eization system (A05) auto-matically causes selected safety-relief valves to open, depressurizing the reactor so that flow from the low pressure core cooling systems can enter the-

. core in time to limit fuel cladding temperature to less than 2200'F. ADS is

. conservatively required to be OPERABLE whenever reactor vessel pressure. exceeds 135 psig even.though LPCS has incipient flow into the reactor pressure vessel '

at 295 psid and 7115 gpm rated flow at 128 psid,.and LPCI has incipient flow into the reactor pressure vessel at 229 psid and 7450 gpm rated flow st 24 psid. '

ADS-automatically controls eight selected safety-relief valves although the safety' analysis only takes credit for seven valves. It is therefore appro-priate to permit one valve to be out-of-service for up to 14 days without

' mater31 11y reducing system reliability. f 3/4.5.3 SUPPRESSION POOL The supression pool is required to be OPERABLE as part of the ECCS to ensure that a sufficient supply of water is available to the HPCS, LPCS and LPCI systems in the event of a LOCA. This limit on suppression pool minimum water volume ensures that sufficient water is available to permit recirculation cooling flow to the core. The OPERABILITY of the suppression pool in OPERATIONAL CONDITIONS 1, 2 or 3 is required by Specification 3.6.3.1. '

Repair work might require making the suppression pool inoperable. This specification will permit those repairs to be made and at the same time give assurance that the irradiated fuel has an adequate cooling water supply when the suppression pool must be made inoperable, including draining, in OPERATIONAL CONDITION 4 or 5.

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

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In OPERA',.'ONAL CONDITIONS 4 and 5 this specification permits one ECCS-to be capable _of~ manual realignment'in order to perform its. vessel injection-function.' TheLECCS requiring manual realignment shall:be; capable'-.of being-

, frealigned from control room panels within 20 minutes.

LIn OPERATIONAL CONDITIONS 4 and 5, LPCI "C" is proh_ibitedl.from simultaneously operating;with the Alternate Decay Heat Removal System (ADHRS).

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A9007231/SNLICFLR - 37

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NLNb/hi 1 L i ,f ' fREFUELING OPERATIONS-8ASES' 3/4.9.7 CRANEiTRAVEL - SPENT FUEL AND UPPER CONTAINMENT FUEL' STORAGE POOLS

. The. restriction on movement of loads in excess of the nominal weight of a fuel. assembly,over other fuel assemblies in_the storage pools ensures that in the event:this" load is dropped (1) the activity release will be: limited to that contained in a single fuel assembly, and (2) any possible distortion of fuel'in the storage racks will not result'in a critical array. This assumption is consistent with the activity release assumed in the safety analyses.

I 3/4.9.8 and:3/4.9.9 WATER LEVEL REACTOR VESSEL and WATER LEVEL - SPENT FUEL L AND UPPER CONTAINMENT FUEL STORAGE POOL 5 ..

The. restrictions on minimum water level ensure that sufficient water' depth-is available to remove 99% of the assumed 10% iodine gap activity. released from ;

the rupture of an irradiated _ fuel assembly. This minimum water depth'is consistent with the assumptions of the accident analysis. 7 3/4.9.10 CONTROL ROD REMOVAL l These-specifications ensure that maintenance or repair of control rods or control rod drives will be performed under conditions that limit the probability.

L .of inadvertent criticality. The requirements for simultaneous removal of more-t than one control rod are more stringent since the SHUTDOWN MARGIN specification ,

( provides for the core to_ remain subcritical with only one control rod fully sithdrawn. g g gp g 3/4.9.11 'RESIOUAL HEAT REMOVAL AND COOLANT CIRCULATION '

-The requirement that at least one residual heat removal loop be OPERABLE and in operation or that an alternate method capable of decay heat removal be

!~ demonstrated and that an. alternate method of coolant mixing be in operation ensures that (1) sufficient cooling capacity is available to remove decay heat L and maintain the water in the reactor pressure-vessel below 140*F as required L

during REFUELING, and (2) sufficient coolant circulation would be available- i through the reactor core to assure accurate temperature indication and to distribute and prevent stratification of the poison in the' event it becomes necessary to actuate the standby liquid control system.

I.

The requirement to have two shutdown cooling mode loops OPERABLE when there L is less'than 22 feet 8 inches of water above the reactor vessel flange ensures-L that a single failure of the operating loop will not result in a complete loss L of_ residual heat removal capability. . With the reactor vessel head removed and l 22 feet 8 inches of water above the reactor vessel flange, a large heat sink is L available for core cooling. Thus, in the event a failure of the operating RHR loop, adequate time is provided to initiate alternate methods capable of decay heat removal or emergency procedures to cool the core. ._

3/4.9.12 HORIZONTAL FUEL TRANSFER SYSTEM ( EAT-l The purpose of the horizontal fuel transfer system specification is to L control personnel access to those potentially high radiation areas immediately adjacent to the system and to assure safe operation of the system.

GRAND GULF-UNIT 1 B 3/4 9-2 Amadu.ut A. -

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,, a, LN_ SERT 1 T0_ BASES 3/4'.9.11 Page B3/4 9-2 <

An OPERABLE' residual heat removal (RHR) system shutdown cooling. mode train-consists of~at.least one OPERABLE RHR pump and one OPERABLE RHR heat exchanger train..

INSERT 2 TO BASES 3/4.9.11 ,

Page B3/4 9-2 The alternate decay heat removal system (ADHRS)Lis designed-to provide decay heat removal via the plant service water system.- ADHRS is capable of=

s maintaining reactor coolant temperatures below technical specification -limits '

,during REFUELING _ operations. For specification 3.9.11.2 additional:

i , requirements are imposed during ADHRS operation since_ADHRS is not designed as

-a: safety-related system and has no onsite power supply capability. An- !

t0PERABLE ADHRS in the reactor cooling mode consists of two OPERABLE ADHRS pumps and;two OPERABLE ADHRS heat exchangers. _i In 0PERATIONAL CONDITION 5, simultaneous operation of the ADHRS in the reactor cooling mode and RHR system shutdown cooling mode trains "A" and "B" is prohibited for certain alignments of these systems.

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.A9007231/SNLICFLR - 38

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RESOLUTIONS OF POTENTIAL ADHRS ADVERSE SYSTEM INTERACTIONS l H

-1.- ' As identified in Entergy Operations - GGNS submittal dated .

-March 3 -1989 (AECM-89/0051)' and noted in the Safety Evaluations for ,

-OL Amendment 58,. dated March 16, 1989 and OL Amendment'59, dated March 27,_.1989, the potential exists during OCs 4 and 5 for the.

'x Loperation'of the ADHRS to' impact the' operation of two safety related systems. ;The potential adverse interactions involve the operability.

of:the LPCI "A" and LPCI. "B" subsystems and one division of

-suppression. pool water-level instrumentation. .The NRC determined, 3

as-documented in the Safety Evaluation for OL Amendments 58 and 59,: q that prior to long term licensing of the ADHRS these potential-interactions must be resolved. 1 LPCI "A" and LPCI "B" Subsystem Operability

-2.- During ADHRS operation with low reactor cavity water level, the '

j potential exists for the LPCI "A" or LPCI "B" keep fill low pressure '1 alarm to come.on,-.thus making the LPCI "A" or LPCI "B" subsystems 1 inoperable.- ;

During RF03 operation of'ADHRS,-the keep fill low pressure alarm did i not occur. Although'the interaction did not occur in RF03, there q does exist some potential for occurrence during future operations !

under certain combinations of ADHRS operating parameters coincident- l with hypothetical LPCI "A" or LPCI "B"' keep fill low pressure alarm setpoint drif t. , i Entergy Operations - GGNS considers the ADHRS system to be

>4 acceptable since (1) the probability of achieving the combination of-

~

parameters required to cause this interaction is -low (as evidenced. :

~by RF03-operations), (2) the Operations Annunciator Response !

Instruction adequately addresses actions to be taken if the keep 7 y' fill low, pressure alarm comes on, and-(3) sufficient flexibility 3 exists in the ADHRS, LPCI "A" cod LPCI "B" subsystems to promptly ;}

restore and maintain.LPCI "A" or LPCI "B" operability if the adverse. i interaction does occur. Also, Entergy Operations - GGNS will revise !

the proper procedure to place a warning for the operator that during a

o certain conditions of ADHRS operation the LPCI "A" or LPCI "B" keep fill low pressure alarm may occur.

S_up.pression Pool Water Level Instrumentation Operability m

3. The LPCI "C" jockey pump keeps the reference leg filled with water i g' for one division of suppression pool water. level instrumentation.

Ki The jockey pump must be turned off when the ADHRS is operating h; because a valve upstream of the suction to the jockey pump must be Q{

closed.

J ~The design and operational characteristics of the ADHRS have been reviewed. The ADhRS while operating does produce sufficient pressure to keep the reference leg of the affected division of suppression pooi water level instrumentation filled. The jockey w

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pump isinot needed to maintain the instrumentation operable during' 1 f'

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ADHRS operation.

?, Conclusion j- T '

f

-4.. Based 'on the above, Entergy.0perations - GGNS believes the potentia ~l

adverse system. interactions created by the ADHRS have been satisfactorily evaluated-and resolved to permit long term ADHRS ;

licensing.

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