Text

Proposed Tech Specs,Correcting Inconsistency Between Requirements Re Suppression Pool High Alarm
	ML20215L324
Person / Time
Site:	LaSalle
Issue date:	04/29/1987
From:	; COMMONWEALTH EDISON CO.
To:	;
Shared Package
ML20215L318	List: ML20215L315; ML20215L324;
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	NUDOCS 8705120188
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r ATTACHMENT B TECHNICAL SPECIFICATION CHANGE REQUEST LASALLE COUNTY STATION UNITS 1 AND 2 PROPOSED CHANGES TO APPENDIX A REVISED PAGES:

NPF-11 NPF-18 XIX XIX 3/4 3-30 3/4 3-30 3/4 5-8 3/4 5-8 3/4 5-9 3/4 5-9 3/4 6-16 3/4 6-19 3/4 6-17 3/4 6-20 3/4 6-18 3/4 6-21 B 3/4 5-2 B 3/4 5-2 B 3/4 6-3 B 3/4 6-3 B 3/4 6-3a (new page) B 3/4 6-3a (new page) 8705120188 870429 PDR ADOCK 05000373 P PDR

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INDEX ONLy LIST OF FIGURES FIGURE PAGE 3.1.5-1 SODIUM PENTA 80 RATE SOLUTION TEMPERATURE /

CONCENTRATION REQUIREMENTS ............................. 3/4 1-21 3.1.5-2 SODIUM PENTABORATE (Na2 8to0 1 s

10 H 2O)

VOLUME / CONCENTRATION REQUIREMENTS ...................... 3/4 1-22

3. 2.1-1 MAXIMUM AVERAGE PLANAR LINEAR HEAT GENERATION RATE (MAPLHGR) VERSUS AVERAGE PLANAR EXPOSURE, INITIAL CORE FUEL TYPES 8CR8176, 8CR8219, AND 8CR8071 ................................................ 3/4 2-2 3.2.1-2 MAXIMUM AVERAGE PLANAR LINEAR HEAT GENERATION RATE (MAPLHER) VERSUS AVERAGE PLANAR EXPOSURE, FUEL TYPE BP8CR8299L ................................... 3/4 2-2a 3.2.3-1 MINIMUM CRITICAL POWER RATIO (MCPR) VERSUS t AT RATED FLOW ........................................ 3/4 2-5 3.2.3-2 K f FACTOR .............................................. 3/4 2-6 3.4.1.1-1 CORE THERMAL POWER (% OF RATED) VERSUS TOTAL CORE FLOW (% OF RATED) ................................. 3/4 4-lb 3.4.6.1-1 MINIMUM REACTOR VESSEL METAL TEMPERATURE VS. REACTOR VESSEL PRESSURE ............................ 3/4 4-1B 4.7-1 SAMPLE PLAN 2) FOR SNUBBER FUNCTIONAL TEST . . . . . . . . . . . . . 3/4 7-32 B 3/4 3-1 REACTOR VESSEL WATER LEVEL ............................. B 3/4 3-7 8 3/4.4.6-1 CALCULATED FAST NEUTRON FLUENCE (EJ1MeV) at 1/4 T l

t AS A FUNCTION OF SERVICE LIFE .......................... B 3/4 4-7 l 5.1.1-1 EXCLUSION AREA AND SITE BOUNDARY FOR GASEOUS AND LIQUID EFFLUENTS ................................... 5-2 5.1. 2 LOW POPULATION ZONE .................................... 5-3 l

l 6.1-1 CORPORATE MANAGEMENT ................................... 6-11 6.1-2 UNIT ORGANIZATION ...................................... 6-12 1 l l i 6.1-3 MINIMUM SHIFT CREW COMPOSITION ......................... 6-13 B sh.c. 2-1 Sw n u :. m &tt.cvd s %;s. .. 8 sh aa LA SALLE - UNIT 1 XIX Amencment No.10

')

FOR INFORMATION C -

ONLY TABLE 3.3.3-2 (Continued) l C .

u, '

[HERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION Sa'TPOINTS

? '

l~,

ALLOWABLE

, TRIP I11HCTION TRIP SEIPOINT VAluE !

c

5

-4 C. IlivlSION 3 TRIP SYSitM

1. Iqt.g SYSTEM .

~

a. Reactor Vessel Water Level - Low Low, Level 2 >- 50 inches * >- 57 inches *

l. Drywell Pressure - til0h 1 1.69 psig 5 1.89 psig c Iteactor Vessel Water Level - liigh, Level 8 1 55.5 inches a $ 56 inches *

d. Condensate Stonage lank Level - Low 1 715'7" y . 1 715'3" ,

n

e. Suppression Pool Wate. Level - High 3 700'1" 6 2 Inch'eJ -700

2"-- f 3 Int bG

t. Pannp Discharge Pressure - liigh 1 120 psig 1 1181 psig 9 IIPCS System Flow Rate - Low 1 1000 gpa 1 900 gpa

,,, l. Manua1 InLiaLion HA NA

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s

,,, D. -

I n '2,,. Of POWER s,

o ! 1.16 kv Emergency Bus Undervoltage (Loss of Voltage)# -

a. 4.16 Kv Basis

1) Divisions 1 and 2 2625 i 131 volts with 2625 1 262 volts with

< 10 second time delay 1 11 second time delay 2496 i ,12h volts with 2496 1 250 volts with 3 4 second time delay 1 3 second time delay

2) Division 3 2870 i 143 volts with 2870 1 287 volts with 5 10 second time delay i 11 second time delay

~

~^See li.i.es Figure B 3/4 3-1.

Ihe .c ..re inverse time delay voltage relays or instantaneous voltage relays with a time delay. The voll.iq. . shown are the maximtun that will not result in a trip. Lower voltage conditions will result in des ed trip times.

ik L e ve t se ce re.-enced to c< j> lan t c'k<rl<h of G'if f<< f !! indnes. (Se e Ayn 8 %.i.2-d

EMERGENCY CORE COOLING SYSTEMS FOR INFORMATION hky '

3/4.5.3 SUPPRESSION CHAMBER .

~

LIMITING CONDITION FOR OPERATION 3.5.3 The suppression chamber shall ba OPERA 8LE:

a. In OPERATIONAL CONDITION 1, 2 or 3 with a contained water ' volume of at least 128,800 ft3 , equivalent to a level of r, R n in. - V Yx e nch es,, ,

b. In OPERATIONAL CONDITION 4 or 5" with a contained water volume of at 3

least 70,000 ft , equivalent to a level of 14 n " u , except that the l suppression chamber . level may be less than the limit may be

, drained in OPERATIONAL CONDITION 4 or 5* provided that: /2 fee p 7lac4o

1. No operations are performed that have a potential for draining j the reactor vessel,

2. The reactor mode switch is locked in the Shutdown or Refuel position,

3. The condensata storage tank contains at least 135,000 available gallons of water, equivalent to a level of 14.5 feet, and

4. The HPCS system is OPERA 8LE per Specification 3.5.2 with an OPERA 8LE flow path capable of taking suction from the condensate i storage tank and transferring the water through the spray sparger to the reactor ves::al.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, 4, and 5*. l ACTION:

a. In OPERATIONAL CONDITION 1, 2, or 3 with the suppressien chamber water level less than the above limit, restore the water level to within the limit within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 .

l b. In OPERATIONAL CONDITION 4 or 5* with the suppression chamber water l 1evel less than the above limit or drained and the above required conditions not satisfied, suspend CORE ALTERATIONS and all operations

.that have a potential for draining the reactor vessel and lock the reactor mode switch in the Shutdown position. Establish SECONDARY CONTAINMENT INTEGRITY within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

5ee Specification 3.6.2.1 for pressure suppression requirements.

"The suppression chamber is not required to be OPERABLE provided that the reactor vessel head is removed, the cavity is flooded or being flooded from the suppression pool, the spent fuel pool gates are removed when the cavity is flooded, and the water level is maintained within the limits of Specifications 3.9.8 and 3.9.9.

c leva Nm o# M 'l l.~'*

h "C A" 4

Levat., re ce<arn ced. Io a p t.:s +

(See Gwe 6 1/y. G . 2 -e)

LA SALLE - UNIT 1 3/4 5-6 Amendment No. 18

. l TCO INFORMATION -

EMERGENCY CORE COOLING SYSTEMS m)f31:I b

LIMITING CONDITION FOR OPERATION (Continued)

ACTION (Continued) k c. With one suppression chamber water level instrumentation channel

inoperable, restore the inoperable channel to OPERA 8LE status within

.y u 7 days or verify the suppression chamber water level to be greater

% than or equal 20 ft Oi in er 10 ft 0 in, as applicable, at least l

[ onc curs by local indication.

d. With both suppression chamber water level instrumentation channels

] inoperable, restore at least one inoperable channel to OPERABLE u '

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 rf . e suppression chamber water level to be greater than or

< equal t 20 ft 25 in ;r l' ft 0 17, as applicable, at least once l lj per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by local indication.

( o SURVEILLANCE REQUIREMENTS J 4.5.3.1 The suppression chamber shall be determined OPERABLE by verifying:

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

4 b. inche.s '

'1. 20 ft 2i in at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . l I

2. 1? ft 0 in at least,once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . l

-ty fed 7anche,$ "

b. Two suppression chamber water level instrumentation channels OPERABLE by performance of a:

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 CALIBRATION at least once per 18 months, with the low water level alarm setpoint at greater than or equal to 20 ft Ota.** - 3 .7n c.4 e s * *'

I.

4.5.3.2 With the suppression chamber 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 footnota conditions

to be satisfied.

i

The suppression chamber is not required to be OPERABLE provided that the

reactor vessel head is removed, the cavity is flooded or being flooded from

the suppression pool, the spent fuel pool gates are removed when the cavity is flooded, and the water level is maintained within the limits of Specifi-cations 3.9.8 and 3.9.9.

LA SALLE - UNIT 1 3/4 5-9 Amendment No.18 kf le. vel h n G.~e aceJ! Ju a plo., / ele abh of G99 Qei u do

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- - - = - - - - - - - - - - - - - - -- *-

JOR BIFORMATION CONTAINMENT TYSTEMS Qh(( ~

3/4.6.2 DEPRESSURIZATION SYSTEMS h

I SUPPRESSION CHAMBE -

D LIMITING CONDITION FOR OPERATION

.y t 3.6.2.1 The suppression chamber shall be OPERA 8LE with:

a. The pool water:

M 1. Volume between 131,9003 ft and 128,800 3ft , equivalent to a

> 1evel betweenp2C ft. 10 fa. .ad OC ft. 2'. fa., and a i i 2. M erage temperature of 100*F* during OPERATIONAL

) -

a)

ONDITION 1 or 2, except that the maximum average temperature maybepersgtedtoincreaseto:

105*F, during testing which adds heat to the suppression i d chamber.

O w b) 110*F with THERMAL POWER less than or equal to 1% of I t RATED THERMAL POWER.

4 c) 120*F with the main steam line isolation valves closed l 0 following a scr m.

I b. Drywell-to-suppression chanNr byp' ass leakage less than or equal to 9 10% of the acceptable A/Jli design value of 0.03 ft2 .

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.

ACTION:

a. With the suppression chamber water level outside the above limits, restore the water level 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 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 1 or 2 with the suppression chamber average water temperature greater than or equal to 100*F, restore the average temperature to less than or equal to 100*F within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-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 , except, as permitted above:

1. With the suppression chamber average water temperature greater than 105'F during testing which adds heat to the suppression chamber, stop all testing which adds heat to the suppression chamber and restore the average temperature to less than or equal to 100*F within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-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 .

2. With the suppression chamber average water temperature greater than 110*F, place the reactor mode switch in the Shutdown position and operate at least,one residual heat removal loop in the suppression pool cooling mode.

3. With the suppression chamber average water temperature greater than 120*F, depressurize the reactor pressure vessel to less than 200 psig within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

W5ee Specification 3.5.3 for ECCS requirements.

NSee Special Test Exception 3.10.8. , ,

FM Le ve t h ce Me.,cedh ajlo.,/ e.levahn of 6995ee f h mClws l ( 5<c G 9 u.~c 6 %. 6. 2 -tJ. .

LA SALLE - UNIT 1 3/4 6-16 Amendment No. 38

703 INFOEMATION CONTAINMENT SYSTEMS ONL'I Mo C k o. tJ LIMITING CONDITION FOR OPERATION (Continued)

~

ACTION: (Continued)

c. With one suppression chamber water level instrumentation channel i inoperable and/or with one suppression pool water temperature I instrumentation division inoperable, restore the incperable I instrumentation to OPERABLE status within 7 days or verify suppres-sion chamber water level and/or temperature 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 by local indication.

d. With both suppression chamber water level instrumentation channels inoperable and/or with both suppression pool water temperature instrumentation divisions inoperable, restore at least one i inoperable water level channel and one water temperature division to OPERA 8LE 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 .

e. With the drywell-to-suppression chamber bypass leakage in excess of the limit, restore the bypass leakage to within the limit prior to increasing reactor coolant temperature above 200*F.

SURVEILLANCE REQUIREMENTS 4.6.2.1 The suppression chamber shall be demonstrated OPERABLE:

a. By verifying the suppression chamber water volume to be within the lisits at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in OPERATIONAL CONDITION 1 or 2 by verifying the suppression chamber average water temperature to be less than or equal to 100*F, except:

1. At least once per 5 minutes during testing which adds heat to the suppression chamber, by verifying the suppression chamber average water temperature less than or equa; to 105'F.

2. At least once per 60 minutes when suppression chamber average water temperature is greater than 100*F, by verifying suppression chamber average water temperature less than or equal to 110*F and THERMAL POWER less than or equal to 1% of RATED THERMAL POWER.

3. At least once per 30 minutes following a scram with suppression chamber average water temperature greater than or equal to 100*F, by verifying suppression chamber average water temperature less than or equal to 120*F.

LA SALLE - UNIT 1 3/4 6-17 Amendment No. la

~

FOR INFORMATION CONTAINMENT SYSTEMS ONLY SURVEILLANCE REQUIREMENTS (Continued)

c. By verifying at least two suppression chamber water level instru-mentation channels and at least 14 suppression pool water temperature instrumentation channels, 7 in each of two divisions, OPERA 8LE by performance of a:

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. CHANN'EL CALIBRATION at least once per 18 months,

. T* sapp m s:.,, cW6w S4a // f e with Aheg water level an4 temperature alarm setpoint'.Ser:

".rappm umpocs

1. High water level 120 ft. O i...+a. inche$ I

2. Low water level > 20 ft. 0 ' :. -3 shc4<3 #

_ l

3. High temperature i 100*F l

d. By conducting drywell-to-suppression chamber bypass leak tests and verifying that the A/,/k calculated from the measured leakage is within the specified limit when drywell-to-suppression chamber bypass leak tests are conducted:

1. At least once per 18 months at an initial differential pressure of 1.5 psi, and

2. At the first refueling outage and then on the schedule required for Type A Overall Intagrated Containment Leakage Rate tests by Speci-fication 4.6.1.2.a; at an initial differential pressure of 5 psi, except that, if the first two 5 psi leak tests performed up to that time result in:

l 1. A calculated A/8 within the specified limit, and

2. The A/ 4 calculated from the leak tests at 1.5 psi is < 20% of ~

the specified limit, then the leak tests at 5 psi may be discontinued.

$ leye/ os refere- w/ Jo G p/an/ ele N/E 0 W N N" (See Cgun b 3/%(E h LA SALLE - UNIT 1 3/4 6-18 Amendment No. 18

~

FOR INFORMATION EMERGENCY CORE COOLING SYSTEMS ONT.aY 8ASES ECCS-CPERATING and SHUTDOWM (Continued) the suppression pool into the reactor, but no credit is taken in the hazards analyses for the condensate storage tank water With the HPCS system inoperable, adequate core cooling is assured by the OPERASILITY of the redundant and diversified automatic depressurization system and both the LPC5 and LPCI systems. In addition, the reactor core isolati '

cooling (RCIC) systas, a system for which no credit is taken in the hazards analysis, will automatically provid. askaup at reactor operating pressures on a reactor lee water level condition. The HPCS out-ofsservice period of

. 14 days is based on the demonstret.ed OPERA 81LITY of redundant and diversified low pressure core cooling systans.

The surveillance requirements provide adequate assurance that the HPCS system will be OPERA 8LE when required. 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 soment.

Upon failure of the NPCS system to function properly, if required, the l automatic depressurization systas (ADS) automatically causes selected safety-relief valves to open, depressurizing the reactor so that flow free the low pressure core cooling systems can enter the core in time to limit fuel cladding tamperature to less than 2200*F. ADS is conservatively required to be OPERAELE whenever reactor vessel pressure exceeds 122 psig even though low pressure core

, cooling systans provide adequata core cooling up to 350 psig. ,

ADS automatically controls seven selected safety-relief valves. Six valves are required to be OPERA 8LE although the hazards analysis only takes credit for five valves. It is therefore appropriate to permit one of the required valves to be out-of-service for up to 14 days without materially reducing system reliability.

3/4.5.3 SUPPRESSION CHAMBER The suppression chamber is also required to be OPERA 8LE as part of the m ECCS to ensure that a sufficient supply of water is available to the HPCS, 7 LPCS and LPCI systans in the event of a LOCA. This limit on suppression n chamber minimum water volume ensures that sufficient water is available to permit

, recirculation cooling flow to the core The OPERA 81LITY of the suppression

] chamber in OPERATIONAL CON 0!TIONS , or 3 is required by Specification 3.6.2.1.

Repair work night require making the suppression chamber inoperable.

k> This specification will permit those repairs to be made and at the same time g give assurance that the irradiated fuel has an adequata cooling water supply when the suppression chamber must be made inoperable, including draining, in g CPERATIONAL CONDITION 4 or 5.

3 In OPERATIONAL CONDITION 4 and 5 the suppression chamber minimum required 4

9 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 9 water volume is based on NPSH, recirculation volume, vortex prevention plus a Q 2'-4" safety margin for conservatism. .

LA SALLE - UNIT 1 8 3/4 5-2 Amendment No. 29

~

FOR INFOEMATIon

) CONTAIMNT SYSTEMS "

l BASES 3/4.6.2.

OEPRESSURIZATION SYSTEMS The specifications of this section ensure that the primary containment pressure will not exceed the design pressure of 45 psig during primary Jystem blowdown from full operating pressure.

The suppression chamber water provides the heat sink for the reactor '

coolant systes energy release following a postulated rupture of the systam.

The suppression 'chamoer water volume must ansare the associated decay and structural sensible heat released during reactor coolant system blowdown from i

1020 psig. Since all of the gases in the drywell are purged into tne suppression chancer air space during a loss of coolant accident, the orsssure

of the liquid must not exceed 45 psig, the suppression chameer maximum pressure. The design volume of the suppression chamber, water and air, was 4

octained by consicering that the total volume of reactor coolant and to be considered is discharged to the suppression chancer and that the drywell volume is purged to the suppression chammer. ( 54efsyc 8 J/4,G. 2-/)

l Using the einfaus or saximum water volumes given in this specification,

:)

.. containment pressure during the design basis accident is approximately 39.6 psig which31s below the design pressure of 45 psig. Maximum water volume of l 131,900 ft results jn a downconer submergence of 12.4 ft and the minimus volume of 128,800 ft results in a submergence approximately 8 inches less.

l The majority of the Bogeda tests were run with a submerged length of four feet

I and with completa condensation. Thus, with respect to the downcomer

j. submergence, this specification is adequata.

Should it be necessary to make the suppression chamber inoperable, this l.

i shall only be done as specified in Specification 3.5.3. ,

! Under full power operating conditions, blowdown from an initial suppression chamber water tamperature of 90*F results in a water tamperature of approximately 135'F immediately following blowdown which is below the 200*F used for complete

, condensation via T-quencher devices. At this temperature and atmospheric pressure, l the available NPSH exceeds that requirad by both the RHR and core spray pumps, l thus there is no dependency on containment overpressure during the accident l injection phase.

Experimental data indicates that excessive steam condensing loads can be avoided if the peak bulk temperature of the suppression pool is maintained below 200*F during any period of relief valve coeration with sonic conditions l at the discharge exit for T quencher devices. Specifications have been placed l on the envelope of reactor operating conditions so that the reactor can be depressurized in a timely manner to avoid the regime of potentially hign suppression chamber loadings.

t LA SALLE - UNIT 1 3 3/4 6-3 l _. _. -

l .. . . . . . _ .. .. . - .

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LIST OF FIGURES FIGURE PAGE 3.1.5-1 500IUM PENTA 80 RATE SOLUTION TEMPERATURE /

CONCENTRATION REQUIREMENTS ................ ....... 3/4 1-21 3.1.5-2 500IUM PENTA 80 RATE (Na2 8 to0s 10 H2O)

VOLUME / CONCENTRATION REQUIREMENTS ................. 3/4 1-22 3.2.1-1 MAXIMUM AVERAGE PLANAR LINEAR HEAT GENERATION RATE (MAPLHGR) VERSUS AVERAGE PLANAR EXPOSURE,'

INITIAL CORE FUEL TYPES 8CA183, 8CR233 ANO 8CR711 ................................,............ 3/4 2-2 3.2.3-1 MINIMUM CRITICAL POWER RATIO (MCPR) VERSUS I AT RA1ED FLOW .................................. 3/4 2-5 3.2.3-2 Kf FACTOR ......................................... 3/4 2-6 3.4.6.1-1 MINIMUM REACTOR VESSEL METAL TEMPERATURE VS. REACTOR VESSEL PRESSURE ....................... 3/4 4-19 4.7-1 SAMPLE PLAN 2) FOR SNU88ER FUNCTIONAL TEST ........ 3/4 7-33 8 3/4 3-1 REACTOR VESSEL WATER LEVEL ........................ B 3/4 3-7 8 3/4.4.6-1 CALCULATED FAST NEUTRON FLUENCE (E>1MeV) at 1/4 T AS A FUNCTION OF SERVICE LIFE ..................... 8 3/4 4-7 5.1.1-1 EXCLUSION AREA AND SITE 80VNOARY FOR GASEOUS ANO LIQUID EFFLUENTS .............................. 5-2 i 5.1. 2-1 LOW POPULATION ZONE ............................... 5-3 6.1-1 CORPORATE MANAGEMENT ................... .......... 6-11 6.1-2 UNIT ORGANIZATION ..................... ...... .. 6-12 6.1-3 MINIMUM SHIFT CREW COMPOSITION .................. . 6-13 B 5 .c..m Supp u s., a s i tevei se y m n ...... is 3,4 c - 3 a l

I i

l LA SALLE - UNIT 2 XIX

FOR INFORMATION

. ' TABLE 3.3.3-2 (Continued)

ONLY

' 5-l m EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS g ALLOWA8tE

, TRIP FUNCTION TRIP SETPOINT VALUE g C. DIVISION 3 TRIP SYSTEM U 1. HPCS SYSTEM -

a. Reactor Vessel Water Level - Low Low, Level 2 >- 50 inches *

>- 57 inches

4

b. Drywell Pressure - High 51.69psig 51.89psig i c. Reactor Vessel Water Level - High, Level 8 < 55.5 inches * < 56 inches *

d. Condensate Storage Tank Level - Low I 715'3"

! e. Suppression Pool Water Level - High I]7;;;u 715'7"_g 3 , u 4c34* pt28- { 3,nc4 < 3 "

f. Purp Discharge Pressure - High 1 120 psig 1 110 psig j

g. HPCS System Flow Rate - Low 1 1000 gpa 1 900 gpa

h. Manual Intiation N.A. N.A.

l D. LOSS OF POWER l

, 1. 4.16 kV Emergency Bus Undervoltage .

g (Loss of Voltage)#

<;* a. 4.16 kV Basis U 1) Divisions 1 and 2 2625 i 131 volts with 2625 1 262 volts with

, < 10 second time delay 1 11 second time delay 2496 i 125 volts with 2496 1 250 volts with 1 4 second time delay 1 3 second time delay

2) Division 3 2870 i 143 volts with 2870 1 287 volts with

$ 10 second time delay 1 11 second time delay 4 2. 4.16 kV Emergency Bus Undervoltage

(Degraded Voltage)

a. 4.16 kV Basis

1) Division 3 3814 1 76 volts with 3814 1 76 volts with 10 1 1 second time delay 10 1 1 second time delay TABLE NOTATIONS 1

*See Bases Figure B 3/4 3-1.

These are inverse time delay voltage relays or instantaneous voltage relays with a time delay. The voltages shown are the maximum that will not result in a trip. Lower voltage conditions will result in decreased trip times.

! N.A. Not Applicable .

ey L . o t i s . e G.v.sa d Ic a ,of.s .n / e le ,m lim ;,f' C'9y fe' e / ji ine l', ,

(L c Q < < i e. A % C. 2 - /)

FOR INFORMjiTIop-EMERGENCY CORE COOLING SYSTEMS mdU& . , ..[.

3/4.5.3 SUPPRESSION CHAN8ERf .

l LIMITING CONDITION FOR OPERATION .

3.5.3 The suppression chamber shall be OPERA 8LE: !

a. In OPERATIONAL CONDITION 1, 2, or 3 with a contained water volume of at least 128,800 fta, equivalent to a level of 25 ft 2'; ' . -

y & lu4e:,f #

b. In OPERATIONAL CONDITION 4 or 5" with a contained water volume of at least 70,000 fta; equivalent to a level of it it 0 h. , except that the suppression chamber level may be less than the I t or may be drained in OPERATIONAL CONDITION 4 or 5* provided that: _ n / y ., ,,, g

1. No operations are performed that have a potential for draining the reactor vessel,

2. The reactor mode switch is locked in the Shutdown or Refuel position,

3. The condensate storage tank contains at least 135,000 available gallons of water, equivalent to a level of 14.5 feet, and

4. The HPCS system is OPERA 8LE per Specification 3.5.2 with an OPERA 8LE flow path capable of taking suction from the condensate storage tank and transferring the water through the spray i sparger to the reactor vessel.

APPLICA8ILITY: OPERATIONAL CONDITIONS 1, 2, 3, 4, and 5".

ACTION:

a. In OPERATIONAL CONDITION 1, 2, or 3 with the suppression chamber water level less than the above limit, restore the water level to within the limit within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 4 or 5" with the suppression chamber water level less than the above limit or drained and the above required conditions not satisfied, suspend CORE ALTERATIONS and all operations that have a potential for draining the reactor vessel and lock the reactor mode switch in the Shutdown position. Establish SECONDARY CONTAINNENT INTEGRITY within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

See Specification 3.6.2.1 for pressure suppression requirements.

The suppression chamber is not required to be OPERABLE provided that the reactor vessel head is removed, the cavity is flooded or being flooded from the suppression pool, the spent fuel pool gates are removed when the cavity is flooded, and the water level is maintained within the limits of Specifications 3.9.8 and 3.9.9.

$ k I, eve t o.,

re Cues u) +c a p to,,+ e.fm sy oc gy p,,j p ne4 LA SALLE - UNIT 2 3/4 5-8 6

,tm, -,--- - - , - --,, - - - - . - - , - . , - - , - - - - - , . - - - . , - - , , ,,,vn. ,-na,, , - - - ,,-ec,.-, - , ---,, - --- -,,-n--- , r,,-,, ,,-rn ,,n- - - - - - - , , - - - - - - - - -

FO3 INFORMATION

'ONLY EMERGENCY CORE COOLING SYSTEMS t[ LIMITING C00GITION FOR OPERATION (Continued) -

9v

<$ ACTION: (Continued) f\

c. With one suppression chamber water level instrumentation channel I inoperable, restore the inoperable channel to OPERA 8LE status within Q 7 days or verify the suppression chatber water level to be greater than or equal 20 ft ."., i . r " ft 0 in. , as applicable, at Q 1ea*+ - . . . r hours by local indication.

I

d. With both suppression chamber water level instrumentation channels

" inoperable, restore at least one insperable channel to OPERA 8LE Y 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

\u (he suppression chamber water level to be greater than or equal tE 2C ft 2" in. r 10 ft ' ., as applicable, at least once

] per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by local indication.

.C '

SURVEILLANCE REQUIREMENTS g

4.5.3.1 The suppression chamber shall be determined OPERA 8LE by verifying:

a. Thewaterleveltobegrehterthanorequalto,asapplicable:

- V V1 o n cla s oc

1. 2C ft 2'; 'n. at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2. 10ft0in.atleastongeper12 hours.

j

- / 2 f< ef 7 e b c t4e s

b. Two suppression chamber water level instrumentation channels OPERA 8LE by performance of a:

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 CALIBRATION at least once per 18 months,

~ '

with the low water levet alarm setpoint at greater than or equal to 2C ft e in. -3 4cA,3 W

.a 4.5.3.2 With the suppression chamber level less tha'n' 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.

"The suppression chamber is not required to be OPERABLE provided that the reactor

vessel head is removed, the cavity is flooded or being flooded from the suppres-sion pool, the spent fuel pool gates are removed when the cavity is ficoded, and the water level is maintained within the limits of Specifications 3.9.8 and 3.9.9.

LA SALLE - UNIT 2 3/4 5-9 y V L e al h re %eaced lo affan / e f; va % cfG'i9 0ef !! < , c he s j ( Sec C,9 u.~c. d % C . 2 -1).-

FOR I.biFOEMATION CONTAu.or smos 3/4.6.2 DEPRE55URIZATION SYSTEMS om'r i SUPPRESSION CHAMERf'

LIMITING CONDITION FOR OPERATION

_Q p. 4 2 3.6.2.1 The suppr'sssion chamber shall be OPERA 8LE with:

I a. The pool water:

Y 1. Volume between 131,900 fta and 128,800 ft3 , equivalent to a.

> level between 20 TL 10 !... ...J 20 f t. 2', i... , and a I

2. average temperature of 100*F during OPERATIONAL T

ONDITION 1 or 2, except that the maximum average temperature R may be pomitted to increase to:

D- a) 105*F, during testing which adds heat to the suppression

-g chamber.

N b) 110*F with THERMAL POWER less than or equal to 1% of C RATED THERMAL POWER.

N c) 120'F with the main steam line' isolation valves closed foll. ming a scram.

' ,{'

b. Drywell-to suppression chamber bpass sleauge 1en than or equal to i 10% of the acceptable A/JE design value of 0.03 fta, APPLICA8ILITY: OPERATIONAL CONDITIONS 1, 2, and 3.

ACTION:

a. With the suppression chamber water level outside the above limits, restore the water level 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 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 1 or 2 with the suppression chamber average water temperature greater than or equal to 100*F, restore the average temperature to less than or equal to 100*F within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-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 , except, as pemitted above:

1. With the suppression chamber average water temperature greater than 105*F during testing which adds heat to the suppr4ssion cham-ber, stop all testing which adds heat to the suppression chamber and restore the average temperature to less than or equal to 100*F within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at lesst 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 .

2. With the suppression chamber average water temperature greater than 110*F, place the reactor mode switch in the Shutdown position and operate at least one residual heat removal loop in the suppression pool cooling mode.

3. With the suppression chamber average water temperature greater than 120*F, depressurize the reactor pressure vessel to less than 200 psig within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

5ee specification 3.5.3 for ECCS requirements.

LA SALLE - UNIT 2 3/4 6-19 -

+k L evsl is (See fipe.r e6 Gw 3/1. G.cid.Rha)

-i pia., f ele va k & M9 Qe+ li .4y

FTl INF0F2iAT.

rw ION

. v i u ,.

CONTAIMIENT SYSTEMS /

LIMITING CONDITION FOR OPERATION (Continued) l*k L

(nCwtcjc 5 ACTION: (Continued)

c. With one suppression chamber water level instrumentation channel inoperable and/or with one suppression pool water temperature instrumentation division inoperable, restore the inoperable instrumentation to OPERA 8LE status within 7 days or verify suppres-sfon chamber water level and/or temperature 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 by local indication,

d. With both suppression chamber water level instrumentation channels inoperable and/or with both suppression pool water temperature instrumentation divisions inoperable, restore at least one inoperable water level channel and one water temperature division to OPERA 8LE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at.least HOT SHUTOOWN 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 .

e. With the drywell-to-suppression chamber bypass leakage in excess of the limit, restore the bypass leakage to within the limit prior to increasing reactor coolant temperature above 200*F.

SURVEILLANCE REQUIREMENTS 4.6.2.1 The suppression chamber shall be demonstrated OPERABLE:

a. By verifying the suppression chamber water volume to be within the limits at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

b. At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in OPERATIONAL CONDITION 1 or 2 by verifying the suppression chamber average water temperature to be less than or equal to 100*F, except:

1. At least once per 5 minutes during testing which adds heat to the suppression chamber, by verifying the suppression chancer average water temperature less than or equal to 105'F.

l

2. At itast once per 60 minutes when suppression chamber average i

water temperature is greater than 100*F, by verifying suppression chamber average water temperature less than or equal to 110*F and THERMAL POWER less than or equal to 1% of RATED THERMAL POWER.

3. At least once per 30 minutes following a scram with suppression chamber average water temperature greater than or equal to 100*F, by verifying suppression chamber average water temoerature less thin or equal to 120*F.

LA SALLE - UNIT 2 3/4 6-20

. !?k[T:;,j.}'

- CONTAI N SYSTEp5 ff.'

W i7& "47 f,

SURVEILLANCE REQUI'EMENTS R (Continued) n 1_ __ _

c. By verifying at least 2 suppression chamber water level instru-mentation channels and at least 14 suppression pool water temperature instrumentation channels, 7 in each of two divisions, OPERA 8LE by performance of a:

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 CALIBRATION at least once per 18 months,

, T Sup,sn.% c W 6e ~ m/t fe wit f.he 3water level andjtamperature alarm setpoint fer: ,

duppmu. Moo f. i

1. High water level 120 ft 0 h. + 2 is c 4.c 5 p

2. Low water level > 25 ft ' '-

. - 3 / a c 5tc 5 #

3. High temperature i 100*F

d. By conducting drywell-to-suppression chamber bypass leak tests and verifying that the A/4 calculated from the measured leakage is within the specified Ifait when drywell-to-suppression chamber bypass leak tests are conducted:

1. At least once per 18 months at an initial differentisi pressure of 1.5 psi, and

2. At the first refueling outage and then on the schedule required for Type A Overall Integrated Containment Leakage Rate tests by Speci-fication 4.6.1.2.a., at an initial differential pressure of 5 psi, '

except that, if the first two 5 psi leak tests performed up to that time result in:

1. A calculated A/ 4 within the specified ifmit, and

2. The A/4 calculated from the leak tests at 1.5 psi is 1 20% of the specified limit, then the leak tests at 5 psi may be discontinued.

W bevel is reQscncd lo a f {am) ele a hk of 6 99?cc) /t )$t C bc1 f$et ftjust b 3/h. b. 2. -l LA SALLE - UNIT 2 3/4 6-21

TOR .ThT?O?.MM. om , ion V . J M d.

EMERGENCY CORE CCOLING SYSTEMS BASES ECCS-OPERATING and SHUTOOWN (Continued) the suppression pool into the reactor, but no credit is taken in the hazards 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 hazards analysis, will automatically provide makeup at reactor operating pressures on a reactor low water level condition. The HPCS out-of service period of 14 days is based on the demonstrated CPERABILITY of redundant and diversified low pressure core cooling systems.

The surveillance requirements provide adequate assurance that the HPCS system will be OPERA 8LE when required. 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, if required, the automatic depressurizatibn system (A05) automatically causes selected safety- l 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 versel pressure exceeds 122 psig even though low pressure core cooling systems provide adequate core cooling up to 350 psig.

A05 automatically controls seven selected safety-relief valves. Six O valves are required to be OPERA 8LE although the hazards analysis on19 takes i ! credit for five valves. It is therefore appropriate to pemit one of the M required valves to be out-of-service for up to 14 days without materially reducing system reliability.

-' 3/4.5.3 SUPPRESSION CHAMBER

! gi The suppression chamber is also required to be OPERA 8LE as part of the ECCS 4:i to ensure that a sufficient supply of water is available to the HPCS, LPCS ar.d I

h l LPCI systems in the event of a LOCA. This limit on suppression chamber minimum water volume ensures that sufficient water is available to permit recirculation

% cooling flow to the co The OPERASILITY of the suppression chamber in OPERATIONAL S 1, 2 or 3 is required by Specification 3.6.2.1.

l epair work might require making the suppression chamber inoperable.

l 3 This specification will permit those repairs to be made and at the same time

.h give assurance that the irradiated fuel has an adequate cooling water supply Q when the suppression chamber must be made inoperable, including draining, in OPERATIONAL CONDITION 4 or 5.

In OPERATIONAL CONDITION 4 and 5 the suppression chamber minimum required

'vU water volume is reduced because the reactor coolant is maintained at or below l

\,.)./ 200*F. Since pressure suppression is not required below 212*F, the minimum water volume is based on NPSH, recirculation volume, vortex prevention plus a 2'-4" safety margin for conservatism.

LA SALLE - UNIT 2 B 3/4 5-2 Amendment No. 27

. -. . = _ - . -- . - - . - . ___ -_.

E . '),0 M TN3I m % ,.\e' 7

'[' Q e.f,~ -.

CONTAlleWIT SYSTDW -

A V,l.

4 BASES 3/4.6.2 DEPRESSURIZATION SYSTEMS The specifications of this section ensure that the primary containment pressure will not exceed the design pressure of 45 psig during primary system blowdown from full operating pressure.

The suppression chamber water provides the heat sink for the reactor coolant system energy release following a postulated rupture of the system.

The suppression chamber water volume must absorb the associated decay and structural sensible heat released during reactor coolant system blowdown from 1020 psig. Since all of the gases in the drywell are purged into the suppression chamber air space during a loss of coolant accident, the pressure of the ifquid must not exceed 45 psig, the suppression chamber maximum pressure. The design volume of the suppression chamber, water and air, was obtained by considering that the total volume of reactor coolant and to be considered is discharged to the suppression chapber and that the,drywell volume is purged to the suppression chamber. ( b Fryucc 6 34, 6. 2 - fjS Using the minimum or maximum water volumes given in this specification, containment pressure during the design basis accident is'approximately 39.6

, psig which31s below the design pressure of 45 psig. Maximum water volume of 131,900'ft resultsjnadowncomersubmergenceof12.4ftandtheminimus volume of 128,800 ft results in a submergence approximately 8 inches less.

The majority of the Sogede tests were run with a submerged length of four feet

and with complete condensation. Thus, with respect to the downconer submergence, this specification is adequate.

( Should it be necessary to make the suppression chamber inoperable, this shall only be done as specified in Specification 3.5.3.

Under full power operating conditions, blowdown from an initial suppression chamber water temperature of 90*F results in a water temperature of approximately 135*F immediately following blowdown which is below the 200*F used for complete condensation via T quencher devices. At this temperature and atmospheric pressure,

! the available NPSH exceeds that required by both the RHR and core spray pumps, thus there is no dependency on containment overpressure during the accident !

injection phase. l l ' Experimental data indicates that excessive steam condensing loads can be !

avoided if the peak bulk temperature of the suppression poc1 is maintained i below 200*F during any period of relief valve operation with sonic conditions l l at the discharge exit for T quencher devices. Specifications have been placed I on 2e envelope of reactor operating conditions so that the reactor can be depressurized in a timely manner to avoid the regime of potentially high suppression chamber loadings.

LA SALLE - UNIT 2 8 3/4 6-3 l

l

=.

Cont <ci Suppresvoa Planf c s,s,,,, se ,- L eve i Eteva+,b- A n* si""e .e1,' ",onf"g 1.

2,4 ' ' O r a, 700 2. 43' H,y Lue i LCO

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26, .,

700 I

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g,,,y 3(g o p ,..,+,c.n I cc e l M , 1,z,ar 3

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l+' $87'+ . g z ' 7 Low Leve.l LCC Cpe a fuoh-l C o nl, Iro- 4 et S (vel.,- e 70,000 4 t ')

$uppress,on Peo I L e ve. I So frosn Fs Bases F, g a e. 8 3/462'l La 5 lle - a n ,' + 2.

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

aA . g. A S. AL.e-Js A- Iwa %+, m. ~ # 4 ..- .e- A. _ m. # A S

ATTACHMENT C TECHNICAL SPECIFICATION CHANGE REQUEST LASALLE COUNTY STATION UNITS 1 AND 2 SIGNIFICANT HAZARDS CONSIDERATION f

i.

1 1

1 4

4 2775K

,_-- . ...---.-.,--~.-..--.-,.-,n...,.-,.. , , . - . . . --,,, , .- .-.- - -

4 Commonwealth Edisor has evaluated the proposed Technical Specification Amendment and determined that it.does not represent a significant hazards consideration. . Based on the criteria for defining a significant hazards consideration established in 10CFR50.92, operation of LaSalle County Station Units 1 and 2 in accordance with the proposed amendment will not:

1 )' -Involve a significant increase in the probability or consequences of an accident previously evaluated because:

This. request will raise the technical specification setpoint.for the suppression pool high level alarm, as stated in Technical Specification 4.6.2.1.c.1, one inch to

be consistent with the trip setpoint for suppression pool high water level given in Technical Specification Table 3.3.3-2 and Updated Final Safety Analysis Report (USFAR)

Table 7.3.1. This change will reference all technical specifications concerning suppression pool level to the same plant elevation making the technical specifications consistent with plant indications. This change does not effect the Limiting Condition for Operation _(LCO) for the suppression pool high and low levels as stated in Technical Specification 3.5.3, 3.3.3 or 3.6.2.1.a.l. The suppression pool high level alarm was not considered in the accident

, analysis in Chapter 15 of the UFSAR.

2) Create the possibility of a new or different kind of accident from any accident previously evaluated because:

The change to the suppression pool high level alarm

} setpoint does not effect the LCO for suppression pool level. By making the technical specification limits consistent with plant indications the probability of future

' personnel errors occurring, due to misinterpretation of the technical specifications, will lue reduced.

3) Involve a significant reduction in the margin of safety because:

' The revised suppression pool high level alarm setpoint still provides an adequate margin of warning for the

operators prior to exceeding the LCO for suppression pool water level.

i

l

BACKGROUND On September 14, 1986 it was discovered that an inconsistency existed between the requirements in Technical Specification 4.6.2.1.c and Technical Specification Table 3.3.3-2.

Technical Specification 4.6.2.1.c.1 requires a setpoint of less than or equal to 26 feet 8 inches (equivalent to a plant elevation of 700 feet 0 inches) for the suppression pool high level alarm. Technical Specification Table 3.3.3-2 and the Updated Final Safety Analysis Report (UFSAR) Table 7.3-1, (Reference ( }) require a trip setpoint of less than or equal to 700 feet 1 inch and an allowable value of less than or equal to 700 feet 2 inches for Suppression Pool Water Level - High. Both of these alarm setpoints are below the maximum allowable Suppression Pool level of 26 feet 10 inches indicated in Technical Specification 3.6.2.1.a.1.

DISCUSSION The subsequest investigation into the cause of the inconsistency concluded that one of the contributing factors was the use of different reference points for the suppression pool high level alarm setpoints identified in the technical specifications.

That is the levels were referenced to plant elevation in one case and to the bottom of the suppression chamber in the other. The investigation also found that the reference points used in the technical specifications for the Limiting Conditions for Operations and trip setpoints are not consistent with the instrument references used for the control room and local suppression pool level indications. The instrument zero for all plant suppression pool level indications is set at a plant elevation of 699 feet 11 inches.

These inconsistencies within the technical specifications and between the technical specifications and plant indications have the potential to cause future personnel errors. It is therefore proposed that the following amendments be made to the technical specifications:

1. The suppression pool high water level alarm setpoint in Technical Specification 4.6.2.1.c.1 be raised 1 inch to be consistent with Technical Specification Table 3.3.3-2 and the UFSAR.

2. All references to suppression pool level in the technical specifications be amended to be consistent with plant indications.

3. A figure be added to the technical specification bases which will correlate plant elevation, suppression chamber levels and suppression pool level indications.

3018K

Guidance has been provided in 51 FR 7744, for the application of standards, to license change requests, for determination of the existence of significant hazards ,

considerations. This document provides examples of amendments that are considered likely to' involve significant hazards considerations and amendments which are not considered likely to involve significant hazards considerations. This proposed amendment does

- not involve a relaxation of the criteria used to establish safety limits, a relaxation of the bases for limiting safety system settings or a relaxation of the bases for the limiting conditions for operations. This proposed amendment appears to most closely fit example e.(i) of the amendments considered not likely to involve significant hazards considerations. This amendment request involves an administrative change to technical specifications for the purpose of achieving consistency throughout the technical specifications.

Based on the preceding discussion, it is concluded that the proposed system change clearly falls within all acceptable criteria with respect to the system or component, the consequences of previously evaluated accidents will not be increased and the margin of safety will not be decreased. Therefore, based on the guidance provided in the Federal Register and the criteria established in 10CFR50.92(e), the proposed change does not constitute a significant hazards consideration.

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

ML20215L324

Text

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