Text

Proof & Review Copy of Proposed Tech Spec Changes Re Reactor Protection Response Time
	ML20054E778
Person / Time
Site:	Grand Gulf
Issue date:	06/09/1982
From:	; MISSISSIPPI POWER & LIGHT CO.
To:	;
Shared Package
ML20054E776	List: AECM-82-255, Forwards Proof & Review Copy of Proposed Changes to Tech Specs Re Reactor Protection Response Time; ML20054E778;
References
	NUDOCS 8206140216
	Download: ML20054E778 (18)
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RECM) YYSSF p.g yI 5' WhGI E'.Xi DEFINITIONS If 18 c b '

REACTOR PROTECTION SYSTEM RESPONSE TIME - - - - - - -- - - -- - - -

1.34 REACTOR PROTECTION SYSTEM RESPONSE TIME shall be the time interval,from when the monitored parameter exceeds its trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids. The response time may be measured by any series of sequential, overlapping or total steps such -

that the entire response time is measured.

REP 0FTABLE OCCURRENCE

.i i 1.35 A REPORTABLE O ENCE sh e any of those conditions specified in l Specifications 6.9. nd 6.9 .%

/ 13 R0D DENSITY 1.36 R00 DENSITY shall be the number of control rod notches inserted as a !

fraction of the total number of control rod notches. All rods fully inserted is equivalent to 100% R0D DENSITY.

SECONDARY CONTAINMENT INTEGRITY 1.37 SECONDARY CONTAINMENT INTEGRITY shall exist when:

p a. All Auxiliary Building and Enclosure Building penetrations d.{ required to be closed during accident conditions are either:

1. Capable of being closed by an OPERABLE secondary containment

'autcmatic isolation system, or

2. Closed by at least one manual valve, blind flange, or deactivated automatic valve or damper, as, applicable, secured in its closed position, except as provided in Table 3.6.6.2-1 of Specification 3.6.6.2.

b. All Auxiliary Building and Enclosure Building equipment hatches and blowout panels are closed and sealed.

c. The standby gas treatment system is OPERABLE pursuant to Specification 3.6.6.3.

d. The door in each access to the Auxiliary Building and Enclosure Building is closed, except for normal entry and exit.

e. The sealir.g mechanism associated with each Auxiliary Building and Enclosure Building penetration, e.g., welds, bellows or 0-rings, is OPERABLE. .

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8206140216 820609 -

PDR ADOCK 05000416 PDR A

GRAND GULF-UNIT 1 BAN 5 1982 1-7 ,.

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ffA REACTIVITY CONTROL SYSTEMS .

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.c SURVEILLANCE REOUIREMENTS 4.1.3.3 Each control rod scram accumulator shall be determined OPERABLE:

a'. er 7 days by verifying that the indicated pressure is

>Afo.O -1520 30, e sig unless the control rod is inserted and disarmed or scramme .

b. At least once per 18 months by: .

l. Performance of a: .

a) CHANNEL FUNCTIONAL TEST of the leak detectors, and b) CHANNEL CALIBRATION of the pressure detectors, and

~ verifying an alarm setpoint of 1520 + 30, -0 psig on decreasing pressure.

2. Measuring and recording the time, for up to 10 minutes, that l' each individual accumulator check valve maintains the associated accumulator pressure above the alarm set point wj'th no !

m control rod drive pump operating.

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,cSI

'i

. FIRE DETECTION INSTRUMENTATION INSTRUMENT LOCATION MINIMUM INSTRUMENTS OPERABLE

ROOM NO. ELEV. ROOM NAME ZONE (1) HEAT (2) FLAME SM0KE(3)

c. Auxiliary Building (Continued)

~'~

59. IA407 166' MCC AREA 2-8 2 NA 1

60. IA410 166' MCC AREA 2-8 2' NA 1

61. 1A417 166' NORTH CORRIDOR 2-8 NA

. NA 14

62. 1A420 166' SOUTH CORRIDOR 2-7 NA NA 4

63. IA424 166' SET DOWN AREA 2-7 NA .NA 2

64. IA428 166' WEST CORRIDOR 2-7 NA NA 4

65. IA432 166' FPC AND CU PUMP RM 2-7 NA NA 1

66. 1A434 166' PASSAGE 2-7 NA NA 1

67. 1A519 -

185' STORAGE AREA 2-9 NA NA 4

68. 1A527 185' LOAD CENTER AREA 2-9 NA NA 5

69. 1A539 185' CABLE CHASE 2-15 NA NA 1

70. 1A602 208'10" STORAGE AREA 2-13 NA NA 6 --

{g 71. 1A603 208'10" PASSAGE 2-13 NA NA 3

72. 1A604 208'10" HANDLING AREA 2-13 NA NA 13

73. 1A,606 245' H$h EQUIP AREA 2-13 NA NA 9

d. Diesel Generator Building

1. Unit 1 El. 158'-0" HPCS 6-9A 7 6 NA Generator i 2. Unit 1 El. 158'-0" Bus 8 6-9B 7 6 NA Generator

3. Unit 1 El. 158'-0" Bus A 6-9C 7 6 NA Generator

e. Standby Service Water Pump House

1. Pump House A 2-1 NA NA 1

2. Valve Room A 2-1 NA NA 1

3. Pump House B 2-1 NA NA 1

4. Valve Room B 2-1 NA NA 1

f. Charcoal Filter Trains

1. Standby Gas Treatment NA 1 NA NA System Filter Train Auxiliary Building (Allison Thermistor Wire)

El. 139'-0"

2. Control Room Standby NA 1 NA NA Fresh Air System Filter

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i_J s Train, Control Building (Allison Thermistor Wire)

E1. 133'-0" GRAND GULF-UNIT 1 3/4 3-79 APR 151982 - 32 1 k 9 g.

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CONTAINMENT SPRAY

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~ LIMITING CONDITION FOR OPERATION

' 3.6.3.2 The containment' spray mode of the residual heat removal (RHR) system shall be OPERABLE with two independent loops, each loop consisting of:

l a. One OPERABLE RHR pump, and i

b. An OPERABLE flow path capable of recirculating water from the suppression pool through a SSW heat exchanger.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a. With one containment spray loop inoperable, restore the inoperable loop 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 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 .

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b. With both containment spray loops 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 .

1 SURVEILLANCE REQUIREMENTS 4.6.3.2 The containment spray mode of the RHR system shall be demonstrated

OPERABLE:

a. At least once pe" 31 days by verifying that each valve, manual, power operated or automatic, in the flow path that is not locked, sealed or otherwise secured in position, is in its correct position.

b. By verifying that each of the required RHR pumps develops a flow of at least 5650 gpm on recirculation flow through the RHR heat exchange to the suppression pool when tested pursuant to Specification 4.0.5.

c. At least once per 18 months by performance of a system functional ~

test which includes simulated automatic actuation of the system throughout its emergency operating sequence and verifying that each automatic valve in the flow path actuates to its correct position.

Actual spraying of coolant into the primary containment may be excluded from this test.

A ever both RHR subsystems are inoperable, if unable to attain COLD SHUTDOWN a.) equired by this ACTION, maintain reactor coolant temperature as low as actical by use of alternate heat removal methods.

GRAND GULF-UNIT 1 3/4 6-24 MU

l m. -

. ., CONTAINMENT SYSTEMS

g. { ' .' *': f '. - , . . - ,7.m-- ac 3/4.6.6 SECONDARY CONTAINMENT

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SECO'DARY N CONTAINMENT INTEGRITY 2

LIMITING CONDITION FOR OPERATION 3.6.6.1 SECONDARY CONTAINMENT INTEGRITY shall be maintained.

APPLICABILITY: ~ OPERATIONAL CONDITIONS 1, 2~ 3 and *. ,

ACTION:

Without SECONDARY CONTAINMENT INTEGRITY:

a. In OPERATIONAL CONDITION 1, 2 or 3, restore SECONDARY CONTAINMENT INTEGRITY within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-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 .

b. In Operational Condition *

, suspend handling of irradiated fuel in the secondary containment, CORE ALTERATIONS and operations with a I

potential for draining the reactor vessel. The provisions of

. Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.6.1 SECONDARY CONTAINMENT INTEGRITY shall be demonstrated by:

a. Verifying at least once per 31 days that:

1. All Auxiliary Building and Enclosure Building equipment hatches and blowout panels are closed and sealed.

2. The door in each access to the Auxiliary Building and Enclosure i Building is closed, except for routine entry and exit.

3. All Auxiliary Building and Enclosure Building penetrations not

' capable of being closed by OPERABLE secondary containment automatic isolation dampers / valves and required to be closed during accident conditions are closed by valves, blind flanges, or deactivated automatic dampers / valves secured in position.

b. At least once per 18 months:

1. Verifying that one standby gas treatment subsystem will draw down the secondary containment to greater than or equal to 0.25 inches of vacuum water gauge in less than or equal to 120 seconds, and

2. Operating one standby gas treatment subsystem for one hour and maintaining greater than or equal to 0.25 inches of vacuum water in the secondary containment at a flow rate not exceeding

-2300= M.

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^When irradiated fuel is being handled in the secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.

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CONTAINMENT SYSTEMS y# .

SURVEILLANCE REOUIREMENTS (Continued)

b. At least once per 18 months or (1) af ter any structural maintenance on the HEPA filter or charcoal adsorber housTngs, or (2) following painting, fire or chemical release in any ventilation zone communicating with the subsystem by:

1. ' Verifying that the subsystem satisf.ies the 1n place testing

- acceptance criteria and uses .the test procedures 6f Regulatory-Positions C.S.a, C.S.c and C.S.d of Regulatory Guide ,

Revision 2, March 1978, and the system flow rate 1 -E E G- fm 000 t 10% .

2. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b.of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide Revision 2,, March 1978.

3. Verifying a subsystem flow rate o fm i 10% du' ring system l operation when tested in accordance w h ANSI N510-1975.

c. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber ' operation by verifying within 31 days after removal that a laboratory analysis of a repre-ssntative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, Q meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978. ,

d. At least once per 18 months by:

1. Performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence for the: .

a) LOCA, and -

b) Fuel handling accident.

.- 2. Verif9"ing that the pressure dEop across t.he' combined HEPA filters?

and charcoal adsorber banks ,is less than 10.75 inches Water Gauge while operating the filter train at a flow rate of 4000'cfm 10%.

3. Verifying-that the filter train starts and isolation dampers '

open on eacWof the following test signals:

a. Drywell pressure - high, J

b. Reactor vessel water level - low low, level 2,

~

c. Fuel handling area ventilation exhaust radiation - high,- and

d. Fuel handling area pool sweep exhaust radiation - high.

4. - Verifying that the fan can be manually started.

G 5. Verifying that the heaters dissipate 50 5.0 kW when tested in accordance with ANSI N510-1975.

GRAND GULF-UNIT 1 3/4 C 4 '-

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B4

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. 7,. . .. ;

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CONTAINMENT SYSTEMS

{

.a. SURVEILLANCE REQUIREMENTS (Continued) i:t

e. Afte' r each complete or partial replacement of a HEPA filter bank by verifyiag that the HEPA filter banks remove . greater than or equal to 99.95% of the 00P when they are tested in place _in accordanc th

ANSI N510-1975 while~ operatirig"the ' system at a floCrate o fm i 10%.

f. After each complete or partial . replacement of.a. charcoal .adsorber.

bank by. verifying .that the charcoal adsorbers remove greater than

- 99.95%'of a halogenated hydrocarbon refrigerant test gas when .

-they are tested in place in accordance' NSI N510-1975 while operating the system at a flow ra'te.o m 10%.

m l

'N' *FO N 4 Wh +- e N 6ete +- e& *em.w-ee m'-,p 3 3m g,-g i

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APR ,, 7_198{g

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.; (:9 a ._

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q-(m n o g , " ,'"P,'l P.]."'l fatm,a u .i hEU L's J 8 m

g TABLE 3.7.4-2 (Continued) '

5

, SAFETY RELATE 0 MECHANICAL SNUBBERS

C 9

ch SNUBBER SNUBBER

}

NO. AREA ELEVATION NO. AREA. ELEVATION

m. FPCC SYSTEM SSW SYSTEM (Continued)

Q1G41G006R01 9 114 0 Q1P41G002R10 106 Q1G41G006R07 7 99 8 Q1P41G002R12 106 Q1G41G006R07 7 99 8 Q1P41G002R12 106 Q1G41G006R07 7 99 Q1P41G006C01 8 99 Q1G41G015R09 11 204 Q1P41G006C17 8 99 ,

Q1G41G016C08 11 163 025A Q1P41G007R19 -

Q1G41G016R04 11 166 Q1P41G007R20 025A -

Q1G41G016R24 11+ 163 Q1P41G007R23 025A -

R

Q1G41G016R27 11 203 Q1P41G007R23 025A -

Q1G41G016R27 11 203 Q1P41G007R24 025A

'f Q1G41G016R28 11 206 Q1P41G007R24 025A -

DI Q1G41G016R28 11 206 '

Q1G41G016R32 11 197 o. CCW SYSTEM Q1G41G018R06 9 197 Q1P42G002R06 . 9 193.

n. SSW SYSTEM Q1P42G002R06 9 193 Q1P42G002R07 9 186 Q1P41G001R14 7 98 Q1P42G002R07 9 186 Q1P41G001R14 7 98 Q1P42G002R11 9 186 E ---Q1P410002CC A 95 E Q1P42G002R11 9 186 Q1P41G002CO3 8 95 Q1P42G002R13 i 9 186 Q1P41G002R10 8 106 Q1P42G002R13 9 186 N

D

, ~w

... A i

r -i %

s -

MY 'W -

n hh,h;jf51.: n II-seqr]

d I g(g ,, _ i y TABLE 3.7.4-2 (Continued) '- i

=

SAFETY RELATED MECHANICAL SNUBBERS

E G

e'- SNUBBER SNUBBER NO. AREA ELEVATION NO. AREA. ELEVATION w

RESIDUAL HEAT REMOVAL SYST.M (Continued) f. HPCS SYSTEM Q2E12G020R05 7 147 Q1E22G001R10 8 96 Q1E12G020R07 7 147 Q1E22G001R10 8 96 Q1E12G020R07 7 147 Q1E22G002R02 8 96 Q1E12G020R09 7 147 Q1E22G002R02 ~8 96 Q1E12G021R01 8 147 Q1E22G002R03 8 96 ,

Q1E12G021R03 8 146 Q1E22G003R01 11 153 Q1E12G021R03 8 146 Q1E22G003R02 11 153 Q1E12G025R01 8 110 Q1E22G003R03 11 149 t' Q1E12G119R02 7 152 Q1E22G003R04 11 150 Q1E12G159R01 7 126 Q1E22G003R05 11 151 Y Q1E12G159R03 7 126 M AEUm g. RCS LEAK DETECTION SYSTEM c QID2GU col 8 96~

e. S SY TEM Q1E31G116R01 11 169

,, Q1E31G122R01 -

11 149.

Q1E21G001R05 9 96 Q1E31G124R01 11 151 Q1E21G001R07 9 96 Q1E31G124R01 11 151 Q1E21G001R07 9 96 Q1E31G126C01 11 149, Q1E21G002R01 11 150 Q1E31G140R01 11 159 Q1E21G002R01 11 150 Q1E31G140R02 11 159 a- Q1E21G002R03 11 151 Q1E31G140R02 11 159 35 Q1E21G002R04 11 153 Q1E31G148R01 ' 11 151 5 Q1E21G002R05 11 153 Q1E31G148R01 4 11 151 ,'

o Q1E21G002R06 11 153 Q1E31G149R01 - 11 151

, g Q1E21G002R07 11 150 Q1E31G149R01 11 151 .

. CD s '

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. ' ELECTRICAL POWER SYSTEMS $

wnnc I IM & E3 COPY

{ REACTOR PROTECTION SYSTEM ELECTRIC POWER MONITORING !

LIMITING CONDITION FOR OPERATION l 3.8.4.3 Two RPS electric power monitoring assemblies for each inservice RPS l ,

MG set or alternate power supply shall be OPERABLE. .

APPLICABILITY: At all times.

ACTION:

a. With one RPS electric power monitoring assembly for an inservice RPS MG set or alternate power supply inoperable, restore the inoperable power monitoring system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or remove the associated RPS MG set or alternate power supply from service,

b. With both RPS electric power monitoring assemblies for an inservice RPS MG set or alternate power supply inoperable, restore at least one electric power monitoring assembly to OPERABLE status within 30 minutes or remove I the associated RPS MG set or alternate power supply f rom service. l i

SURVEILLANCE REQUIREMENTS l 1

4. 8. 4.3 The above specified RPS electric power monitoring assemblies shall be l determined OPERABLE: I

a. At least once per six months by performance of a CHANNEL FUNCTIONAL TEST, and I b. At least once per 18 months by demonstrating the OPERABILITY of over voltage, under-voltage and under-frequency protective

instrumentation by performance of a CHANNEL CALIBRATION including l simulated automatic actuation of the protective relays, tripping l logic and autput circuit breakers and verifying the following setpoints

+0 -2 7 132EVAC,

1. Over-voltag

+2 1-0

2. Under-voltagt 117YVAC, and

-d*A

3. l Under-frequenv[57VHz

.3fN 7 1982 GRAND GULF-UNIT 1 3/4 8-46 13 -

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E rREStoENT -

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VICE PRESIDENT ' " CE 8

8"I "E83 DENT ' SENI

SAF"Y VICE PRESID fVICE PRESIDENT. .

ItJFORMATIONAL An,I!$RITivE "'" '""

SERVICES SEnviceS

" huS!!Y " $$! TEE AREA AFF S PUBLIC AFFAIRS AND ENVIRON-l l '. 1 Of[1EttTAI Site MATTERS -!

VICE PRESIDEllT I l

~

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\_SERVICES./

CUSTOMER .

MAtlAGER - ASStSTANI VICE N g CENLRAL FR0rERTY & l l ' SITE Ce Site I PEEStoENT, NUCt. EAR MANAGER a SENVICES ,

w FNODUCTION m l 8

_ _ [

_______ __i

l l - l el / r CORPORATE. (7 otaECT 4 FRUCllASING &

MANACER I _1_ _ /

l_NUCt.EE-[ MANAGER,

._ _1- - -

MANACER OF 4 STAR

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MANAGER

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' IIECHTIE l QUALITY PLAN NUCLEAR NUCLEAR PLANT WIAGER gi

'4ANAGER STORES ASSURANCE M CER SERVICES &

STArv l

ENGINEERING &

STAFF NUCLEAA kROJECT l AS$1ST l l FROJECT l E

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[' 'FROoUCTION g LIrY ASSudANCE Pl.AMT SAFETY g

l: BUYERS OPERATIONS SUPER- REVIEW Coluf!TTEE 4

VISOR & STAFF

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LECEND t >e .

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........ ..sEviEu & MONrTORINc 0

M TECHNICAL & AoHINISTRATIVE AUTl!ORITY L e. . rNoErENoENT REvaEu . N t'i'

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SENIO R VICE PRESIDENT, ,

FJUCLEAR O

MANAGER OF ASSISTANT VICE PRESIDENT OUAllTY ASSURANCE NUCLEAR PRODUCTION NUCLEAR PLANT MANAGER MANAGER OF MA?JAGER NUCLE AR PL A?tT fiUCLEAR SE RVICES ENGINEER!!JG AANAGER OF MANAGERGF NUCLEAR MANAGER OF AD.'!INISTRATIVE NUCLEAR RECOROS SAFETY AND FUELS AcutNIST11ATO R & LICENSitJG BUSINESS SERVICES I I I _

CIVIL / STRUCTURAL / OPERATIONAL ENGINEERING ELECTRICAL SUPERVISO R SUPERVISOR CORPORATE MECHANICAL ENVIRONMENTAL ANALYSIS SERV!CES ROUP OF SAFETY OF LICENSING HEALTH PHYSICIST GROUP G P.0UP GROUP GROUP m

4b>

4 f~ijuge ' 4. 2d-/

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lIW/$

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CONTAINMENT SYSTEMS T'.n i* in ' ? 6 3 " -s ' u c r3 my '

-. ... ... .] i: , f j CONTAINMENT INTERNAL PRESSURE LIMITING CONDITION FOR OPERATION

3. 6.1. 7 Containmen Auxil y Building differential pressure shall be maintained betwee .

and%Qpqid. l APPLICABILITY: 0 OITIONS 1, 2 and 3.

ACTION: ,

With the containment to Auxiliary Building differential pressure outside of the specified limits, restore the differential pressure to within the limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT SHDTD0%N within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTD0%N within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , i

SURVEILLANCE REQUIREMENTS

4. 6.1. 7 The containment to Auxiliary Building differential pressure shall be determined to be within the limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

g .4 i

I;0V s T

GRAND GULF-UNIT 1 3/4 6-10 .

.m.. ie g<a RADI0 ACTIVE EFFLUENTS r r7 . .p,. ...

I,1.Ey ,q,nyg

. . u ip7;g,f u s ,

f

, MAIN CONDENSER l - - -

LIMITING CONDITION FOR OPERATION 3.11.2.7 The gross radi ~

I35m~

'ty (gamma) rate of the noble gases Xe 6 Xe-133, Xe-135, Xe-138, Kr-85? r-87, Kr-88 measured at the r i. :..._e- / 'in ejcctar shall be limite ess than or equal to 380 millicuries /second. 5 APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2, and 3 wo%.Mnsgj Reandde

,c I ACTION:

With th r radioactivity rate of the noble gase Xe- e-13 Xe-135, Xe-138, Kr-857 Kr-87, and Kr-88 at the m'ia condenref 2. accia exceeding 380 mil s/second, restore the gro'ss radioactivity release rate to within its limit within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

SURVEILLANCE REQUIREMENTS 4.11.2.7.1 The' radioactivity release rate of noble gases near the outlet of the main condenser air ejector shall be continuously monitored in accordance with Specification 3.3.7.12. '

4.11.2.7.2 'The gross radoactivity release rate of the noble gases Xe-133m, Xe-133, Xe-135, Xe-138, Kr-85m, Kr-87, and Kr-88 from the main condenser air ejector shall be determined to be within the limits nf Specification 3.11.2.7 at the following frequencies by performing an isotopic analysis of a representative sample of gases taken at the discharge (prior to dilution and/or discharge) of the nain condenser air ejector: '

a. At least once per 31 days.

b. Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months following an increase, as. indicated by the Condenser-Air Ejector Noble Gas Activity Monitor, of greater than 50%, after fact'oring out increases due.to changes in THERMAL POWER level, in the nominal steady state fission gas release from the primary coolant.

. 9 f

EEB t 1982

, GRAND GULF-UNIT 1 3/4 11-17

\ ~

ML20054E778

Text

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