Text

Proposed Tech Specs 3/4.1.3.5 Re Control Rod Scram accumulators,3/4.4.4.3.2 Re Reactor Coolant Sys Operational leakage,3/4.5.1 Re ECCS - operating,3/4.5.3 Re ECCS, Suppression Chamber & 3/4.6.2.1 Re Suppression Chamber
	ML20134A193
Person / Time
Site:	LaSalle
Issue date:	01/20/1997
From:	; COMMONWEALTH EDISON CO.
To:	;
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ML20134A180	List: ML20134A178; ML20134A193;
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	NUDOCS 9701280202
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4 ATTACHMENT B PROPOSED AMENDMENTS TO THE LICENSE / TECHNICAL SPECIFICATIONS ;

NPF-11 NPF-18 i

3/41-9* 3/4 1-9 i 3/4 1-10 3/4 1-10 3/4 4-6* 3/4 4-7*

3/4 4-7 3/4 4-8 INSERT A INSERT A i 3/4 4-8 3/4 4-9 3/45-1* 3/45-1*

3/4 5-2* 3/4 5-2*

i 3/4 5-3 3/4 5-3 INSERT B INSERT B 3/4 5-4* 3/4 5-4* 1 3/4 5-5 3/4 5-5 INSERT C INSERT C 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 5-3 8 3/4 5-3 INSERT D INSERT D

These pages are provided for information only.

i B-1 9701280202 970120 PDR ADOCK 05000373 P PDR ,.

7-REACTIVIU CONTROL SYSTEM g g{ y CONTROL ROD SCRAM ACCUMULATORS

/% Choges LIMITING CONDITION FOR OPERATION As A l

I 3.1.3.5 All control rod scram accumulators shall be OPERABLE.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 5*.

ACTION

I a. In OPERATIONAL CONDITION 1 or 2:

1

1. With one control rod scram accumulator inoperable:

1 a) Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , either: 1

1) Restora the inoperable accumulator to OPERABLE status, or

2) Declare the control rod associated with the inoperable accumulator inoperable.

b) 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 .

2. With more than one control rod scram accumulator inoperable, declare the associated control rod inoperable and ;

a) If the control rod associated with any inoperable scram l accumulator is withdrawn, immediately verify that at least one CRD pump is operating by inserting at least one withdrawn control rod at least one notch by drive l

water pressure within the normal operating range or

( place the reactor mode switch in the Shutdown position, b) Insert the inoperable control rods av* disarm the associated directional control valve. either:

1) Electrically, or

2) Hydraulically by closing the drive water and exhaust water isolation valves.

Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b. In OPERATIONAL CONDITION.5 with:

1

1. One withdrawn control rod with its associated scram accumulator inoperable, insert the affected control rod and i disarm the associated directional control valves within I hour, either:

I a) Electrically, or b) Hydraulically by closing the drive water and exhaust water isolation valves.

l I 2. More than one withdrawn control rod with the associated scram accumulator inoperable or with no control rod drive pump operating, immediately place the reactor mode switch in the Shutdown position.

At least the accumulator associated with each withdrawn control rod. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

ia e .e om 1 3/41-9 Amendment No. 94

I REACTIVITY CONTROL SYSTEM l

SURVEILLANCE REQUIREMENTS 1

1 4.1.3.5 Each control rod scram accumulator shall be determined OPERABLE:

a. At least once per 7 days by verifying that the indicated pressure is greater than or equal t.) 940 psig unless the control rod is inserted and disarmed or scrammed. .

b. At 1 ast one per 18, onths y: '

1. Pe forman of a:

a) CHANNEL 'UNCTI L TES of t leak stecto , and 6

b) C NNEL CA IBRATI _of th pres re de ctors, ith the j alarm setpo t > 94Rs psig decr sing ressur j l 1

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LA SALLE - UNIT 1 3/4 1-10 Amenomenc ,,v. 39 A

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l O Of4') M REACTOR COOLANT SYSTEM ho b'14114CE6 3/4. 4. 3 REACTOR COOLANT SYSTEM LEAKAGE V

LEAKAGE DETECTION SYSTEMS LIMITING CONDITION FOR OPERATION 3.4.3.1 The following reactor coolant system leakage detection systems shall be OPERABLE:

a. The primary containment atmosphere particulate radioactivity monitoring system,

b. The primary containment sump flow monitoring system, and

c. Either the primary containment air coolers condensate flow rate app % T! 3 system or the primary containment atmosphere gaseous rw. u vity monitoring system.

l APPLICA8ILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

1 ACTION:

With only two of the above required leakage detection systems OPERABLE, ' opera-tion may continue for up to 30 days provided grab samples of the containment atmosphere are obtained and analyzed at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when the required Caseous and/or particulate radioactive monitoring system is inoperable; other-wise, 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 .

SURVEILLANCE REQUIREMENTS 4.4.3.1 The reactor coolant system detection systans shall be demonstrated OPERABLE by:

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a. Primary containment atmosphere particulate and gaseous monitoring systems performance of a CHANNEL CHECK at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION at least once per 18 months.

b. Primary containment sump flow monitoring system-performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION TEST at least once per 18 months."

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c. Primary containment air coolers condensate flow rate monitoring system-perfonnance of a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION at least once per 18 months.

"The specified 18 month interval may be waived for Cycle 1 provided the surveillance is.ptrformed during Refuel 1.

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'I LA SALLE-UNIT 1 3/4 4-6 Amendment No. 24 I

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REACT 0P COOLANT SYSTEM OPERATIONAL LEAKAGE LIMITING CONDITION FOR OPERATION 3.4.3.2 Reactor coolant systen leakage shall be limited to:

a. No PRESSURE BOUNDARY LEAKAGE.

b. 5 gpa UNIDENTIFIED LEAKAGE.

c. 25' gpa total leakage averaged ove any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period.

d. 1 gpa leakage at a reactor coolant systes pressure at 1000 2 50 psig from any reactor coolant systes pressure isolation valve specified ;

in Table 3.4.3.2-1. !

e. 2 gpa increase in UNIDENTIFIED LEAKAGE within any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period.

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APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION: j

a. With any PRESSURE BOUNDARY LEAKAGE, be in at least HOT SHUTDOWN i within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

b. With any reactor coolant systen leakage greater than the limits in b and/or c, above, reduce the leakage rate to within the limits within 1 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 .

c. With any reactor coolant systen pressure isolation valve leakage ,

greater than the above limit, isolate the high pressure portion of the affected system from the low pressure portion within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at least two closed valves, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the'following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

d. With one or more high/ low pressure interface valve leakage pressure monitors inoperable, restore the inoperable monitor (s) to OPERABLE status within 7 days or verify the pressure to be less than the alarm setpoint at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by local indication; !

restore the inoperable monitor (s) to OPERABLE status within 30 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

e. With any reactor coolant system leakage greater than the limit in e, above, identify the source of leakage 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 .

SURVEILLANCE REQUIREMENTS k4.3.2.1 The reactor coolant system leakage shall be demonstrated to be within each of the above limits by:

a. Monitoring the primary containment atmospheric particulate and

~ gaseous radioactivity at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months q- % ~

LA SALLI - UNIl 1 ygg{gpA 3/4 kI -

Ane dme hhlcalSpecifica on .02xes notopp ,

I 1 l

ATTACHMENT B <

PROPOSED AMENDMENTS TO THE LICENSE / TECHNICAL SPECIFICATIONS !

i INSERT A 4.4.3.2.1 The reactor coolant system leakage shall be demonstrated to be within each of the above limits on average once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months not to exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

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i B-2

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REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)

b. Monitoring the primary containment sump flow rate on average once pe 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months not to exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ," and

\

c. Monitoring the primary containment air coolers condensate flow rata at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . -

4.4.3.2.2 Each reactor coolant system pressure isolation valve specified in Table 3.4.3.2-1 shall be demonstrated OPERA 8LE:

a. Pursuant to Specification 4.0.5, except that in lieu of any leakage testing required by Specification 4.0.5, each valve shall be demonstrated OPERABLE by verifying leakage to be within its limit:

1. At least once per 18 months, and

2. Prior to returning the valve to service following maintenance, repair or replacement work on the valve which could affect its leakage rate.

The provisions of Specification 4.0.4 are not applicable for entry into OPERATIONAL CONDITION 3.

b. By demonstrating OPERABILITY of the high/ low pressure interface valve leakage pressure monitors by performance of a: )

1

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

2. CHANNEL CALIBRATION at least.once per 18 months, With the alars setpoint for the:

1. HPCS system i 100 psig.

2. LPCS sy'stes 1 500 psig.

3. LPCI/ shutdown cooling systes 1 400 psig.

4. RHR shutdown cooling i 190 psig.

5. RCIC 1 90 psig.

" Technical Specification 4.0.2 does not apply. l

( I LA SALLE - UNIT 1 3/4 4-8 Amendment No. 80

rrforenabn 0n) 3/4.5 EMERGENCY CORE C00 LING SYSTEMS & Cha$es j 3/4.5.1 FCCS - OPERATING 1

LIM m NG COND M ON FOR OPERATION j 3.5.1 ECCS divisions 1, 2 and 3 shall be OPERA 8LE with

a. ECCS division 1 consisting of:

1. The OPERABLE low pre'ssure core spray (LPCS) system with a flow

- path capable of taking suction from the suppression chamber and transferring the water through the spray sparger to the reactor

, vessel.

1

2. The OPERABLE low pressure coolant injection (LPCI) subsystas "A" i

i of the RHR system with a flow path capable of taking suction frem the sgpression chamber and transferring the water to the reactor vessel.

i 3.

4 At least 5 OPERABLE" ADS valves.

', b. l 4

ECCS division 2 consisting of:

I 1.

The OPERABLE low pressure coolant injection (LPCI) subsystems

'5" and "C" of the RNA systas, each with a flow path capable of l taking suction from the suppression chamber and transferring the

water to the reacter vessel.

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2. At least 5 OPERABLE ** ADS valves.

! c. . ECCS division 3 consisting of the OPERA 8LE high pressure core spray i (HPCS) systan with a flow path capable of taking suction from the j suppression chamber and transferring the water through the spray sparger ta the reactor vessel.

APPLICABILITY: OPERATIONAL CONDITION 1, 2*# and 3*.

"The AD5 is not requued to be OPERABLE when reactor steam done pressure is less than or equal to 122 psig.

- See Specification 3.3.3 for trip system operattlity.

'see special Test Exception 3.10.5.

LA SALLE - UNIT 1 3/4 Ir-1 Amendment No. 29

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I h4ormtion ont 1

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EMERGENCY CORE COOLING SYSTEMS pM g LIMITING CONDITION FOR OPERATION (Continued) 4 ACTION: -

a. For ECCS division 1, provided that ECCS divisions 2 and 3 are OPERABLE:

1. With the LPCS system inoperable, restore the inoperable LPCS system to OPERABLE status within 7 days.

2. With LPCI subsysten "A" inoperable, restore the inoperable LPCI l subsystea "A" to OPERABLE status within 7 days.

3. With the LPCS system inoperable and LPCI subsystem "A" inoperable, restore at least the inoperable LPCI subsystem "A" or the inoperable LPCS system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . -

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

! b.

For ECCS division 2, provided that ECCS divisions 1 and 3 are OPERABLE: .

l 1. With either LPCI subsystem "B" or "C" inoperable, restore the inoperable LPCI subsystem "B" or "C" to OPERABLE status within I 7 days.

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2. With both LPCI subsystems "B" and "C" inoperable, restore at least l

the inoperable LPCI subsystem "B" or "C" to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , j 3.

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

c.

l For ECCS division 3, provided that ECCS divisions 1 and 2 and the RCIC system are OPERABLE: -

1.

With ECCS division 3 inocerable, restore the inoperable division to OPERABLE status within 14 days.

l 2.

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

"wnenever two or more RHR subsystems are inoperable, if unable to attain COLD SHUTDOWN as required by this ACTION, maintain reactor coolant temperature as low as practical by use of alternate heat removal methods.

LA SALLE - UNIT 1 3/4 5-2

EMERGENCY CORE COOLING SYSTEMS LIMITING CONDITION FOR OPERATION (Continued) .

ACTION: (Continued) ;

For ECCS divisions 1 and 2, provided that ECCS division 3 is OPERABLE: 1 d.

1. With LPCI subsystas "A" and either LPCI subsystas "B" or "C" inoper-able, restore at Isast the inoperable LPCI subsysten "A" or inoper-able LPCI subsysten "8" or "C" to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

2. With the LPCS systes inoperable and either LPCI subsystems "B" or "C" inoperable, restore at least the inoperable LPCS system or inoper-able LPCI subsystes "B" or "C" to OPERA 8LE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .*

3. Otherwise, be in at least NOT 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

e. For ECCS divisions 1 and 2, provided that ECCS division 3 is l OPERA 8LE and divisions 1 and 2 are otherwise OPERABLE:

1. With one of the above required ADS valves inoperable, restore the inoperable ADS valve to OPERA 8LE status within 14 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor steam done pressure to < 122 psig within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2. With two or more of the above required ADS valves inoperable, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor steam done pressure to < 222 psig within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

f. With an ECCS discharge line ' keep filled" pressure alare instrumenta- .

( tion channel inoperable, perform Surveillance Requirement 4.5.1.a.1 at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

g. With an ECCS header delta P instrumer.tation channel inoperable, restore the inoperable channel to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or determine ECCS header delta P locally at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; otherwise, declare the associated ECCS inoperable. -

h. With Surveillance Requirement 4.5.1.d.2 not performed at the required interval due to low reactor steam pressure, the provisions of Specifica-tion 4.0.4 are not applicable provided the surveillance is performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure is adequate to perform the test.

i. In the event an ECCS system is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.6.C within 90 days describ-ing the circumstances of the actuation and the total accumulated actua- I tion cycles to date. The current value of the usage factor for each )

affected safety injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.

j. With one or more ECCS corner room watertight doors inoperable, restore all the inoperable ECCS corner room watertight doors to OPERA 8LE status within 14 days, otherwise, be in at least NOT 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 .

"Whenever two or more RHR subsystems are inoperable, if unable to attain COLD

( SHUTDOWN as required by this ACTION, maintain reactor coolant temperature as

(.s low as practical by use of alternate heat removal methods.

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

ATTACHMENT B PROPOSED AMENDMENTS TO THE LICENSEITECHNICAL SPECIFICATIONS INSERT B

k. With ADS accumulator backup compressed gas system bottle pressure less than 500 psig, restora ADS accumulator backup compressed gas system bottle pressure to greater than 500 psig within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or declare the associated ADS valves inoperable, and follow Action e of this specification.

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SURVEILLANCE REOUIREMENTS ,

4.5.1 ECCS divisiens 1, 2, and 3 shall be demonstrated OPERABLE by:

a. At least once per 31 days for the LPCS, LPCI, and HPCS systems:

1

1. Verifying by venting at the high point vents that the system piping from the pump discharge valve to the system isolation valve is filled with water. j l

l 2. Performance of a CHANNEL FUNCTIONAL TEST of the:

a) Discharge line " keep filled" pressure alare instrumentation, and b) Hender delta P instrumentation.

3. 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.

{

l 4. Verifying that each ECCS corner room watertight door is closed, except during entry to and exit from the room.

b. Verifying that, when tested pursuant' to Specification 4.0.5, each:

1

1. LPCS pump develops a flow of at least 6350 gpm against a test line pressure greater than or equal to 290 psig. ,

l 2. LPCI pump develops a flow of at least 7200 gpm against a test '

l line pressure greater than or equal to 130 psig.

i 3. HPCS pump' develops a flow of at least 6250 gpm against a test line pressure greater than or equal to 370 psig. i

c. For the LPCS, LPCI and HPCS systems, at least once per 18 months:

1. Performing 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 injection of coolant into the reactor vessel may be excluded !

from this test.

2. Performing a CHANNEL CALIBRATION of the:

a) Discharge line " keep filled" pressure alarm instrumentation and verifying the:

1) High pressure setpoint allowable value and the low pressure setpoint allowable value of the:

( ,

n OFF1Gbon Only No changes i

i LA SALLE - UNIT 1 3/4 5-4 Amendment No. 105 l

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EMERGENC CORE COOLING SY' STEMS .

SURVElllANCE RE0VIREMENTS (Continued)

(a) LPCS system to be $500 psig and 245.5 psig, respectively.

(b) LPCI subsystem "A" to be s400 psig and 241.0 psig, respectively, i (c) LPCI subsystem "B" to be $400 psig and 238.5 psig, respectively.

, (d) LPCI subsystem "C" to be $400 psig and 245.0 l psig, respectively. !

1

2) Low pressure setpoint allowable value of the HPCS system to be 242.5 psig.

b) Header delta P instrumentation and verifying the setpoint allowable value of the: l

1) LPCS system and LPCI subsystems to be 1 psid.

s 2) HPCS system to be 5 i2.0 psid greater than the normal indicated AP.

I 4 3. Deleted.

4. Visually inspecting the ECCS corner room watertight door seals ,

and room penetration seals and verifying no abnormal degradation, damage, or obstructions.

d. For the ADS by: _p l ReA2 i. rat least once per 31 days, performing a CHANNEL FUNCTIONAL TEST of the accumulator backup compressed gas system low pressure wj/gINSERTC

' g tem. -

2. At least once per 18 months:

a) Perfoming a. system functional test which includes t

' simulated automatic actuation of the si , tem throughout its emergency operating sequence, but excluding actual valve

- actuation.

b) Manually opening each ADS valve and observing the expected change in the indicated valve position.

4) 7erforming a CHANNEL CALIBRATION of the accumulator backup compressed gas system low pressure alarm system and verifying an alarm setpoint of 500 + 40, - O psig on decreasing pressure.

LA SALLE - UNIT 1 3/4 5-5 Amendment No. 105

ATTACHMENT B PROPOSED AMENDMENTS TO THE LICENSE / TECHNICAL SPECIFICATIONS l

lNSERT C l At least once per 31 days:

1 a) Verify ADS accumulator supply header pressure is a 150 psig.

l b) Verify ADS accumulator backup compressed gas system bottle pressure is 2 500 psig."

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. EMERGENCY CORE C0OLING SYSTEMS [nformctt/on Only 3/4.5.3 SUPPRE5SION CHAM 3ERf ko baMjd5

, LIMITING CONDITION FOR OPERATION ,

l 3.5.3 The suppression chamber shall be OPERABLE: ,

j a. In OPERATIONAL CONDITION 1, 2, or 3 with a contained water volume of i at least 128,800 fts, equivalent to a level of -41/2 inches.**

i i b. In OPERATIONAL CONDITION 4 or 5* with a contained water volume of at l 1 east 70,000 fts, equivalent to a level of -12 feet 7 inches.**

APPLICA81LITY: OPERATIONAL CONDITIONS 1, 2, 3, 4, and 5*. -

ACTION:

l 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 I hour 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 .

i

! b. In OPERATIONAL CONDITION 4 or 5* with the suppression chamber water level less than the above limit, suspend CORE ALTERATIONS and all l operations that have a potential for draining the reactor vessel and lock the reactor mode switch in the Shutdown position. Establish SECONDARY CONTAINMENT IKTEGRITY within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

(

See Specification 3.6.2.1 for presst.re suppression requirements. i

The suppression chamber is not required to be OPERA 8LE 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.

{ '; ** Level is referenced to a plant elevation of 699 feet 11 inches (See Figure 8 3/4.6.2-1).

LA SALLE - UNIT 1 3/4 5-8 Amendment No. If . 81 9

_ _ _ , _ <-.r- -

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

. EMERGENCY CORE COOLING SYSTEMS

{ LIMITING CONDITION FOR OPERATION (Continued)

~

l kTION: (Continued) .

c. With one suppression chamber water level instrumentation charmel i inoperable, restore the inoperable channel to OPERABLE status within i 7 days or verify the suppression chamber water level to be greater .

I than or equal to -41/2 inches ** or -12 feet 7 inches **, as appilcable, j at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by local indication.

! 6. With both suppression chamber water level instrumentation channels

! inoperable, restore at least one inoperable chanwl 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 l l 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and

! verify the suppression chamber water level to be greater than or

! equal to -41/2 inches ** or -12 feet 7 inches **, 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.

I J

SURVEILLANCE REQUIREMENTS i

l 4.5.3.1 The suppression chamber shall be determined OPERABLE by verifying:

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

j 1. -41/2 inches ** at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

! k

2. -12 feet 7 inches ** at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

[

j Two suppressionofchamber by performance a: water level instrumentation channels OPERABLE]

\i 1. CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , l 2. CHANNEL FUNCTIONAL TEST at least once per 31 days, and l 3. CHANNEL CALIBRATION at.least once per 18 months, i

I

! with the low water level alars setpoint at greater than or equal to

-3 inches.**

i

4.5.3.2 With the suppression chamber level less than the above limit in OPERA-1 TIONAL CONDITION 5*, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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 flooded, and the water level is maintained within the limits of Specifications 3.9.8 and 3.9.9.

- Level is referenced to a plant elevation of 699 feet 11 inches (See FigureB3/4.6.2-1). ,

L-LA SALLE - UNIT 1 3/4 5-9 Amendment No. 59 31

. I ff)"3oMr1Q lCn Csp

.- CONTAINMENT SYSTEMS ~

No Chandg6 '.

3/4.6.2 DEPRE550RIZATION SYSTEMS V

$UPPRESSION CHAMBER LIMITING CONDITION FOR OPERATION 3.6.2.1 The suppression chamber shall be OPERABLE with:

a. The pool water: '

1. Volume between 131,900 ft8 and 128,800 fta, equivalent to a level between +3 inches ** and -4 1/2 inches **, and a

2. Maximum average temperature of 105*F during OPERATIONAL CONDITION 1 or 2, except that the maximum average temperature may be permitted to increase to:

a)

~

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

b) 120'F with the main steam line isolation valves closed following a scram.

4

b. Drywell-to-suppression charmer bypass leakage less than or equal to 10%oftheacceptableA/4.designvalueof0.03ft. 8 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 105'F, stop all testing which adds heat to the suppression pool, and restore the average temperature to less than or equal to 105'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 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.

2. 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 .

'. #See Specification 3.5.3 for ECCS requirements.

D/ ** Level is referenced to a plant elevation of 699 feet 11 inches (See Figure B 3/4.6.2-1).

LA SALLE - UNIl 1 3/4 6-16 Amendment No. 67

. CDNTAINMENT SYSTEMS I

l

, LIMITING CONDITION FOR OPERATION (Continued) j ACTION: (Continued)

I c. With one suppression chamber water level instrumentation channel j ;

inoperable and/or with one suppression pool water temperature l i

h6fe I instrumentation division inoperable, restore the inoperable instrumentation to OPERABLE status within 7 days or verify suppres-sion chamber water level and/or temperature to be within the limits

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

d. fith 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 OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least NOT SHUTDOWN J4wi. hours,a thin the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN ~ within the followinh

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: l

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 105'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 equal to 105'F. '

2.

At least once per 60 minutes when suppression chamber average water temperature is greater than 105'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 105'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. 67

l I

COV"AINurNT SYS M8S 4

S"RVrIUECE REOUTPEMEN"S (Continued) l

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, 1

OPERABLE by performance of a:

beletek 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.

The suppression chamber water level and suppression pool temperature alarm setpoint shall be:

a) Eigh water level 1 +2 inches

b) Low water level 1 -3 inches

c) Righ temperature < 105cr

d. By conducting drywell-to-suppression chamber bypass leak tests at least once per 18 months at an initial differential pressure of 1.5 psi and !

verifying that the A/[k calculated from the measured leakage is within the specified linit.

If any 1. 5 psi leak test results in a calculated A/[k > 20% of the specified limit, then the test schedule for subsequent tests shall be reviewed by the Commission.

l If two consecutive 1.5 psi leak tests result in a cale.ulated A/[k greater than the specified limit, then: f

1. A 1.5 psi leak test shall be performed at least once per 9 months until two consecutive 1.5 psi leak tests result in the calculated A/[k within the specified limits, and

2. A 5 psi leak test, performed with the second consecutive successful 1.5 psi leak test, results in a calculated A/[k within the specified limit, af ter which the above schedule of once per 18 months for only 1.5 psi leak tests may be resumed.

If any required 5 psi leak test results in a calculated A/[k greater than the specified limit, then the test schedule for subsequent tests shall be reviewed by the Commission.

If two consecutive 5 psi leak tests result in a calculated A/[k greater than the specified limit, then a 5 psi leak test shall be performed at least once per 9 months until two consecutive 5 psi leak tests result in a calculated A/[k within the specified limit, after which the above schedule of once per 18 months for only 1.5 psi leak tests may be resumed.

Level is referenced to a plant elevation of 699 feet 11 inches (See Figure B 3/4.6.2-1).

(. LA SALLE - UNIT 1 3/4 6-18 Amendment No. 102

J

. EMERGENCY CORE COOLING SYSTEMS BASES 3/4.5.1 and 3/4.5.2 ECCS - OPERATING and SHUTDOWN (Continued)

ADS automatically controls seven selected safety-relief valves. Six valves are required to be OPERABLE since the LOCA analysis assumes 6 ADS valves in addition to a single failure. It is therefore appropriate to permit

one of the required valves to be out-of-service for up to 14 days without j materially reducing system reliability.

3/4.5.3 SUPPRESSION CHAMBER

The suppression chamber is also 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 chamber minimum. water volume ensures that sufficient water is available to i

permit recirculation cooling flow to the core (See Figure B 3/4.6.2-1). The QFERABILITY of the suppression chamber in OPERATIONAL CONDITIONS 1, 2 or 3 is

' required by Specification 3.6.2.1.

I Repair work might require making the suppression chamber inoperable. .

This specification will pemit 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 chamber must be made inoperable in OPERATIONAL '

CONDITION 4 or 5.

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

INSEAT D

i LA SALLE - UNIT I B 3/4 5-3 Amendment No.105

i i

j 1 ATTACHMENT B i PROPOSED AMENDMENTS TO THE LICENSE / TECHNICAL SPECIFICATIONS INSERT D

" i The ADS accumulator supply header pressure is supplied by the normal

instrument nitrogen system, which has two compressors. This system supplies

[ both the low pressure pneumatic supply header for other pneumatic

! equipment / components in the drywell and the two high pressure ADS j accumulator supply headers. Maintaining the ADS accumulators at greater than i or equal to 150 psig assures that the accumulators are pressurized to greater )

than or equal to 150 psig prior to the loss of the normal pneumatic supply. With j i

an initial pressure of 150 psig, the accumulator is designed to operate the l

. safety / relief valve two times at 70% of drywell design pressure following failure i i

of the pneumatic supply to the accumulator. TS SR 4.5.1.d.1.a assures that this ;

j initial condition is met. The monthly frequency for this SR is adequate, because j i of the reliability of the normal pneumatic supply and multiple alarms that ,

indicate the loss of the normal pneumatic supply. In addition, each ADS !

l accumulator has a low pressure alarm in the control room which will signal 8

when an ADS accumulator is less than 150 psig. This monitoring surveillance and the monthly frequency is consistent with the corresponding SR 3.5.1.3 in l

NUREG 1434, Rev.1.

i l The ADS accumulator backup compressed gas system is comprised of two

! separate bottle banks of nitrogen bottles, one bottle bank for each high

pressure ADS accumulator supply header. One header supplies 3 ADS valve

accumulators, the other header supplies the remaining 4 ADS valves. Each l bank of the ADS accumulator backup compressed gas system has its own

{ indication and alarm for low pressure. This is a backup system provided for long term availability of ADS during and following an accident and therefore is required to be Operable. The monitoring surveillance assures the continued Operability of ADS. The monthly frequency for this SR is adequate, because each ADS bottle bank has a low pressure alarm. Also, unless the normal pneumatic supply is lost, the only losses from the bottles is through gas leakage, which is minimal.

B-5

l l' ATTACHMENT B PROPOSED AMENDMENTS TO THE

] LICENSE / TECHNICAL SPECIFICATIONS ,

INSERT D(Continued)

Action statement k, for the ADS accumulator backup c.ompressed gas system bottle pressure less than 500 psig, is adequate, because this is a backup system to the ADS valve accumulators. The allowed outage time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is reasonable based on the ADS valve accumulators remaining greater than 150 psig, below which the associated ADS valves are inoperable. In addition, the 72 l hours provides sufficient time to obtain full nitrogen bottle (s) and replace low '

pressure bottles with the full bottle (s).

l l

I B-6

REACTIVITY CONTROL SYSTEM CONTROL ROD SCRAM ACCUMULATORS LIMITING CONDITION FOR OPERATION 3.1.3.5 All control rod scram accumulators shall be OPERABLE.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 5*.

l ACTION:

a. In OPERATIONAL CONDITION 1 or 2:

1. With one control rod scram accumulator inoperable:

1 a) Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , either:

1) Restore the inoperable accumulator to OPERABLE status, or

2) Declare the control rod associated with the inoperable-

, accumulator inoperable.

b) 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 .

2. With more than one control rod scram accumulator inoperable, declare the associated control rod inoperable and:

a) If the control rod associated with any inoperable scram accumulator is withdrawn, immediately verify that at least one CRD pump is operating by inserting at least one withdrawn control rod at least one notch by drive water pressure within the normal operating range or place the reactor mode switch in the Shutdown pontion.

' b) Insert the inoperable control rods and disarm the associated directional control valves either:

1) Electrically, or

2) Hydraulically by closing the drive water and exhaust l water isolation valves.

ind6d M OtnerWise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b. In OPERATIONAL CONDITION 5 with:

1. One withdrawn control rod with its associated scram accumulator inoperable, insert the affected control rod and disarm tne associated directional control valves within I hour, either:

a) Electrically, or b) Hydraulically by closing the drive water and exhaust water isolation valves.

2. More than one withdrawn control rod with the associated scram accumulator inoperable or with no control rod drive pump operating, immediately place the reactor mode switch in the Shutdown position.

At least the accumulator associated with each withdrawn control rod. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

LA SALLE - UNIT 2 3/4 1-9 Amendment No. 78

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REACTIVITY CONTROL SYSTDtS ..

e.g

- SURVEILLANCE REOUTRDIDITS

4. L 3.5 Each control rod scram accmulator shall be dotarained OPERABLE: .

a. At least once per 7 days by verifying that the indicated pressure is greater than or equal to 940 psig un ass the control rod is insertad

and disamed or screamed. .

l %. At least once per 38 months by:

l a

L Performance of a:

1 i a) 04Af01EL FUNCTIONAL TEST of the leak detectors, and 1

l b) CHAISEL CALIBRATION of the pressere detectors, with the .

. alam setpoint > N0 psig en decreasing pressure.

l 1

l 1 1 - .

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LA SALLE - tatIT 2 3/4 1-10 ' Amendment No. 21 4

l

1 r

?'

REACTOR C00LANT SYSTEM M48 h 3/4.4.3 REACTOR COOLANT SYSTEM LEAKAGE k LEAKAGE DETECTION SYSTEM 5 l

LIMITING CONDITION FOR OPERATION 4 3.4.3.1 The following reactor coolant system leakage detection systems shall be OPERABLE:

1

a. The primary containment atmosphere particulate radioactivity

', monitoring system,

, b. The primary containment sump flow monitoring system, and j .

' c. Either the primary containment air coolers condensate flow rate monitoring system or the primary containment atmosphere gaseous radicactivity monitoring system.

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

ACTION:

2 i With only two of.the above required leakage detection systems OPERA 8LE, opera-l tion may continue for up to 30 days provided grab samples of the containment

atmosphere are obtained and analyzed at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when the required

{ gaseous and/or particulate radioactive monitoring system is inoperable; other-4 wise, be in at least NOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN witnin the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . ,

SURVEILLANCE REQUIREMENTS 4.4.3.1 The reactor coolant system detection systems shall be demonstrated OPERABLE by:

a. Primary containment atmosphere particulate and gaseous monitoring systems performance of a CHANNEL CHECK at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION at le~ast once per 18 months.

b. Primary containment sump flow monitoring system performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION TEST at least once per 18 months.

c. Primary containment air coolers condensate flow rate monitoring system performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION at least once per 18 months.

l LA SALLE - UNIT 2 3/4 4-7 l

t.

b e REACTOR COOLANT SYSTEN l OPERATIONAL LEAKAGE f LINITING CONDITION FOR OPERATION i

i 3.4.3.2 Reactor coolant system leakage shall be limited to:

l a. No PRESSURE BOUNDARY LEAKAGE.

l b. 5 gpa UNIDENTIFIED LEAKAGE.

c. 25 gpo total leakage averaged over any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period.

! d. I gpa leakage at a reactor coolant system pressure at 1000 2 50 psig

! from any reactor coolant systes pressure isolation valve specified in Table 3.4.3.2-1.

l e. 2 gpa increase in UNIDENTIFIED LEAKAGE within any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period.

I

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.

l ACTION:

i a. With any PRESSURE B0UNDARY LEAKAGE, be in at least HOT SHUTDOWN I

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 b. With any reactor coolant systas leakage greater than the limits in b

and/or c, above, reduce the leakage rate to within the limits within j 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least HDT 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 c. With any reactor coolant system pressure isolation valve leakage .

greater than the above limit, isolate the high pressure portion of J

the affected systas from the low pressure portion within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at .least two closed valves, or be in at least H0T SHUTDOWN l 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 j 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

j d. With one or more high/inw pressure interface valve leakage pressure j monitors inoperable, restore the inoperable monitor (s) to OPERABLE i status within 7 days or verify the pressure to be less than the

{ alars setpoint at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by local indication; j restore the inoperable monitor (s) to OPERABLE status within 30 days j 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 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

e. With any reactor coolant system leakage greater than the limit in e, above, identify the source of leakage 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 INSERTA within the fo11. wing 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS

/474.3.2.1 The reactor coolant systas leakage shall be demonstrated to be t within each of the above limits by: '

a. Monitoring the primary containment atmospheric partic01ste and anseous radioactivity at least once per 12 h -

TecNcS$hMoesnotapply.

LA S - UN 2 -

Amendment No. 64

i i

ATTACHMENT B PROPOSED AMENDMENTS TO THE 4

LICENSE / TECHNICAL SPECIFICATIONS

! INSERT A i

4.4.3.2.1 The reactor coolant system leakage shall be demonstrated to be within each of the above limits on average once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months l not to exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

A i

i i

}

3 i

e i

B-2

~

REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)

h. Monitoring the primary containment sump flow rate on average once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months not to exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ," and

c. Monitoring the primary containment air coolers condensate flow . rate.

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

4.4.3.2.2 Each reactor coolant system pressure isolation valve specified in Table 3.4.3.2-1 shall be demonstrated OPERABLE: .

a. Pursuant to Specification 4.0.5, except that in lieu of any leakage testing required by Specification 4.0.5, each valve shall be demonstrated OPERABLE by verifying leakage to be within its limit:

1. At least once per 18 months, and

2. Prior to returning the valve to service following maintenance, repair or replacement work on the valve which could affect its leakage rate.

The prnvisions of Specification 4.0.4 are not applicable for entry into OPERATIONAL CONDITION 3.

b. By demonstrating OPERABILITY of the high/ low pressure interface -

valve leakage pressure monitors by performance of a:

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

2. CHANNEL CALIBRATION at least once per 18 months, With the alarm setpoint for the:

1. HPCS system 1 100 psig.

2. LPCS system 1 500 psig.

3. LPCI/ shutdown cooling system i 400 psig.

4. RHR shutdown cooling i 190 psig.

5. RCIC 1 90 psig. .

Technical Specification 4.0.2 does not apply.

l LA SALLE - UNIT 2 3/4 4-9 Amendment No. 64

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(- 3/4.5 EMERGENCY CORE COOLING SYSTEMS

. 3/4.5.1 ECCS - OPERATING l LIMITING CONDITION FOR OPERATION i

! 3.5.1 ECCS divisions 1, 2 and 3 shall be OPERABLE with:

i 1

a. ECCS division 1 consisting of:

i i

1. The OPERABLE low pressure core spray (LPCs) systas with a flow

{

j path capable of taking suction from the suppression chamber and transferring the water through the spray sparger to the reactor l vessel. .

j 2.

i TheOPERABLElowpressurecoolantinjection(LPCI) subsystem"A" of the RHR system with a flow path capable of taking suction fres ,

l the suppression chamber and transferring the water to the reactor i

vessel. i 1

3. At least 6 OPERABLE ** A05 valves.

l

{ b. ECC5 division 2 consisting of:

! l

1. The OPERABLE low pressure coo 1Ent ' injection (LPCI) subsystees "B" and "C" of the RHR' system, each with a flow path capable of taking suction'from the suppression chamber and transferring the water to the reactor vessel.

~

2. At least 6 OPERABLE ** ADS valves. -

l c.

ECCS division 3 consisting of the OPERABLE high pressure core spray (HpCS) systan with a flow path capable of taking suction from the suppression chamber and transferring the water through the spray sparger to the reactor vessel.

APPt.ICA81LITY: OPERATIONAL COM ITION 1, 2*# and 38

'~

w*

The AD5'is not required to be OPERABLE when reactor steam done pressure is less than or equal to 122 psig.

y.

- See Specification 3.3.3 for trip system operability.

See Special Test Exception 3.10.6. 1

.a

LA SALLE - UNIT 2 3/4 5-1 Amen h nt No.27

f--.-

.+7 -

~

._ . 11 Ofm4 $0H f

\

h}o ChanneS

DERGENCY CORE COOLING SYSTDis /

v Lhimni CONDITION P0lt OPERATION (Continued)

, _ . . . - 3. :.. _

! a. Per ECCS divisian 1. provided that ECCS divisieE2 andl are SEASLE:

l L With the LPCS system inoperable, restore the inoperable LPCS system to OPetABLE status within 7 days.

I L With LPCI sesysten "A? inoperable, restore the inoperable LPCI l

subsystem "A" to OPERABLE status within 7 days.

! 3. With the LPCS system inoperable and LPCI subsystem "A" inoperable, .

}

restore at least the inoperable LPCI sesystas "A" or the l

insperable LPCS system to OPERASG status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

3 .- .

1 4. Otherwise, he is at least ICT SERDOWI within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ' j and in COLS SENDOWI within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4

b. For ECCS division 2, psevided that ECCS divisions 1 and 3 are OPetA8LE:

.L With either LPCI subsystem "B" er "C" inoperable, restore the l ,, inoperable LPCI subsystem "S" or "C" to OPetA82 status within j 7 days.

! L With both LPCI sesystems "S* and "C" inoperable, restore at least l

! the inoperele LPCI sesystas "B" or "C" to CPERABLE status j within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

1 .

l 3. Otherwise, he in at least ICT SHUTDOWI within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months j and in COLD St#DOWI within the, following 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months se ,

t l

! c. For ECCS division 3, provided that ECCS divisions 1 and 2 and the

{'

4 RCIC system are OPEtA8LE: ,

I l

r I . ,WittrfECES division 3 inoperable, restore the inoperable division . . .

' i. tar WERA83 status within 14 days.

>;~: w.u , ...., q. -

l l

, /i L.i0therwise, be in at least HDT SEEDOWI within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months l

- #ff..andAa> COLD SHIRDOWI within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

~

! d. Per ECCS divisions 1 and 2, provided that ECCS division 3 is OPERABLE:

L With LPCI sesystas "A" and either LPCI subsystem "B" or "C" inoperable, restore at least the inoperable LPCI sesysten "A" i

er inoperele LPCI sesystem "B" or "C" to OPGtABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

'wumever two.or more Rpt sesystams are inoperable, if unable to attain COLD 1

' SREDOWI as required by this ACTION, maintain reactor coolant tamperature as

, low as practical by use of alternata heat removal methods.

j LA SALLE - LMIT 2 3/4 5-2 i

j .

i

7_.. .

l

.. . .. .: .. .A _

o i.

l'- DWIGDICY Coltf COOLING SYSTEMS .

Limweii COMITION POR OP9tATION (Continued)

M . (Continued) l L Wfth the LPCS system inoperabia and eitheF~LPCI subsystems "B" er

! "C" fasperable, restare at least, the inoperable LPCS system or

! insperabie LPCI sesystem "B" or "C" to OPDASLE status within

! 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

1 j

5. Othesise, be in at least NOT StifDOW within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

-and in CDLD SRITDOW within the fellowing 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ",

e. Per ECCS divisions 1 and 2 provided that'ECCS division 5 is I

OPERABLE and divisions 1 and 2 are otherwise OPBASLE:

I L Wth one of the above required A05 valves inoperable, restore the famperable ADS velve to OPGIABLE status within 14 days er be in l st. least NOT SRffD0681 within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor l

stamm dame pressure to 3,122 peig within the next 24 heure.

j L Wfth tus er mete of the above required A05 valves inoperable, -

l be fa at least. NET StifD0b81 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor

staan done pressure ts 3,321 psig withis the next to hours.

f. With as ECC5 discharge line *kasp filled

pressure alars instruenta-ties channel inoperels, perfors Surve111ance Angsf rasent 4.5.1.a.1

. st least:esce per 24-hours. -

i g. Wfth as ECCS header delta Pr instreontation channel inoperable, i

restore the inoperable channel to OPGABLE status wtthin 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or datamine ICCS header delta P locally at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; othemise, declare the associated ECC5 inoperable.

I h. With Surveillance Requirement 4.5.1.d.2 not performed at the required j interval due to law reactor stamm pressure, the previsions of Specifi-l cation 4.0.4 are not applicable provided the surveillance is perfomed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor staan pressure is adequata to perfors the tast.

1.. In the avest an ECCS system is actuated and injects water inta the tBeactor-Casiant System, a Special Report shall be prepared and 4

j

. .semitted to the Commission pursuant to Specification 6.8.C within ~ -~

.Tf.SILdgye, describing the circostances of the actuation and the total

', %- aosmuisted actuation cycles to data. The current value of the

_ a.gusega factor for each affected safety injection nozzle shall be provided la this Special Report whenever its value exceeds 0.70.

J. With one er more ICCS corner reos watertight doors inoperable, restore all the inoperable ECC5 corner room utartight doors to OPetABLE status within 14 days, otherwise, he in at least WT SWTDOW within INSERT *""***"""'"""8""""*"'".'"'"i"'**"*"".

m e two er mere NR subsystans are inoperable, if unebie to attain COLD StlTD0h41 as required by this ACTION, maintain reactor coolant temperature as low as practical by use of alternate heat removal methods.

LA SALLE - 18 TIT 2 , S/4'5-5

1 1

ATTACHMENT B !

PROPOSED AMENDMENTS TO THE LICENSE / TECHNICAL SPECIFICATIONS INSERT B

k. With ADS accumulator backup compressed gas system bottle pressure less than 500 psig, restore ADS accumulator backup compressed gas system bottle pressure to greater than 500 psig within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or declare the associated ADS valves inoperable, and follow Action e of this specification. l l

l I

l B-3

j .

~ ~

' . h

. In4'orntion nly l.

seancy cone coouns sysres NO bl! 63 j

{ . SURVEILUUICE ItEDUTREMENS i

)

4.5.1 ECCS divisions 1,1, and 3 shall be demonstrated OpstABLE by:

! a At feest once per 31 days for the LPCS, LPCI, and WC5 systaos:

1 L Verifying by venting at the high point vents that the systas p1 ing from the pep discharge valve to the systas isolation

, we is filled with water.

i L Performance of a CHAleEL PIBICTICIIAL TEST of the:

~

e) Discharge line " keep f111ed" pressure alarm instrumentation,

and b) Header hita P instrumentation. .

' 3. Verifying that each valve (manus), poue, m..imd, or automatic,)

is the flow path that is not locked, sealed, or otherwise j secured la position, is in its correct position.

. Verifying that oncer ECC5 corner reos watertight. deer is closed. l except during entry to and esit free the room.

b.. Verifying that, when testad pursuant to Specification 4.0.5, each:

1. LPCS pep develops a flow of at least 8350 gym against a test line pressure grestar then or equal to 230 psig. .

, i L LPCI pug develops a flow of at least 7200 se against a test Tine pressure greater then or equal to 130 psig.

-3. WC5 pump develops a flow of at least $200 gpa against a test

+ lima p c, .

cd.;Per,the-s.. LPCS,

,g ~LPCI .

.;. and ressure grestar WC5 systems, at least oncethen per 18 months: or equal to 33 ,_

. % I.'~; Performing a system functional test which includes simulated

$r@~fiautamatic actuation of the systas throughout its mergency operating seguence and verifying that each automatic valve in the flow path Mktuates to its correct position. Actual injection of coolant into the reactor vessel egy be excluded free this test.

2

. m ,:

. : .x .

.* F.

i.ASALII-18 TIT 2 <- 3/4 5-4

! EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REOUIREMENTS (Continued)

2. Performing a CHANNEL CALIBRATION of the:

4 a) Discharge line " keep filled" pressure alarm instrumentation

] and verifying the:

l 1) High pressure setpoint allowable value and the low 4

pressure setpoint allowable value of the: l (a) LPCS system to be $500 psig and 145.5 psig, j' respectively.

(b) LPCI subsystem "A" to.be $400 psig and 241.0 l i

psig, respectively.

(c) LPCI subsystem "B" to be $400 psig and 138.5

psig, respectively.

i 1

(d) LPCI subsystem "C" to be s400 psig and 145.0 !

psig, respectively.

! 2) Low pressure setpoint allowable value of the HPCS

.\

system to be 242.5 psig.

b) Header delta P instrumentation and verifying the setpoint l allowable value of the:

i LPCS system and LPCI subsystems to be

1) 1 psid. ,

2) HPCS system to be 5 2.0 psid greater than the normal indicated AP.

3. Deleted

4. Visually inspecting the ECCS corner room watettight door seals and room penetration seals and verifying no abnormal degradation, damage, or obstructions.

d. For the ADS by:

M face 1. At least once per 31 days, performing a CHANNEL FUNCTIONAL TEST i

WI IN3ENI of the accumulator backup compressed gas system low pressure alarm system.

2. At least once per 18 months:

a) Performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence, but excluding actual valve actuation.

b) Manually opening each ADS valve and observing the expected

_ change in the indicated valve position.

/c) Performing a CHANNEL CALIBRATION of the accumulator backup l

compressed gas system low pressure alarm system and verifying an alara setpoint of 500 + 40, - O psig on decreasing pressure.

LA sal.LE - UNIT 2 3/4 5-5 AMENDMENT NO. 91 s

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

T 1

ATTACHMENT B PROPOSED AMENDMENTS TO THE

, LICENSE / TECHNICAL SPECIFICATIONS 4

INSERT C l At least once per 31 days:

a) Verify ADS accumulator supply header pressure is a 150 psig. l 4

b) Verify ADS accumulator backup compressed gas system i

bottle pressure is 2 500 psig."

d B-4

. _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ . . . _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ . _ _

i nformation Onl i EMERGENCY CORE COOLING SYSTEMS .

NoCA4n4eg i 3/4.5.3 SUPPRESSION CHAMBERf V LIMITING CONDITION FOR OPERATION i !

3.5.3 The suppression chamber shall be OPERABLE:

l l a. In OPERATIONAL CONDITION 1, 2, or 3 with a contained water volume of at least 128,800 fts, equivalent to a level of -41/2 inches.**

! b. In OPERATIONAL CONDITION 4 or 5* with a contained water volume of at

least 70,000 fts, equivalent to a level of -12 feet 7 inches.**

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

1 i ACTION:

i

a. In OPERATIONAL CONDITION 1, 2, or 3 with the suppression chamber water level less than the above limit, restore the water level to i

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 l 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

level less than the above limit, suspend CORE ALTERATIONS and all l i operations that have a potential for draining the reactor vessel and l 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 . .

t i

1 i

1 i l i

4

See Specification 3.6.2.1 for pressure suppression requirements.

*The suppression chamber is not required to be OPERABLE provided that the 1

reactor vessel head is removed, the cavity is flooded or being flooded i 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.

- Level is referenced to a plant elevation of 699 feet 11 inches (see j Figure B 3/4.6.2-1).

i I

LA SALLE - UNIT 2 3/4 5-8 Amendment No. 39 65 4

4

)

I EMERGENCY CORE COOLING SYSTEMS i

LINITING CONDITION FOR OPERATION (Continued)

~

l IACTiON: (Continued)

! c. With one suppression chamber water level instrumentation channel

inoperable, restore the inoperable channel to OPERABLE status within

, 7 days or verify the suppression chamber water level to be greater

than or equal to -41/2 inches ** or -12 feet 7 inches **, 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.

l d. With both suppression chamber water level instrumentation channels i inoperable, restore at least one inoperable channel to OPERABLE 1 status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least HDT SHUTDOWN within the next '

i 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTD9WN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and i verify the suppression chamber water level to be greater than or i equal to -41/2 inches *' or -12 icet 7 inches **, as applicable, at j least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by local indication.

1 i SURVEILLANCE REQUIREMENTS

! 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:

l 1. -4 1/2 inches **- at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

l 2._ -12 feet 7 inches ** at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Two suppression chamber water level instrumentation ch j

i h 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 , t i

j 2. CHANNEL FUNCTIONAL TEST at least once per 31 days, and j 3. CHANNEL CALIBRATION at least once per 18 months, with the low water level alarm setpoint at greater than or equal to

-3 inches.**

4.5.3.2 With the suppression chamber level less than the above limit in OPERA-TIONAL CONDITION 5*, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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 flooded, and the water level is maintained within the limits of Specifications 3.9.8 and 3.9.9.

- Level is referenced to a plant elevation of 699 feet 11 inches (See Figure B 3/4.6.2-1).

LA SALLE - UNIT 2 3/4 5-9 Amendment No. 28, 65

?

I

~

I 1 -

l' t

l gs 3/4.6.2 DEPRES5URIZATION SYSTEMS ((OTrh4 gg /Ot1 hnh i

SUPPRESSION CHAMER

! - i LINITING CONDITION FOR OPERATION f

p, 3.6.2.1 The suppression chamber shall be OPERABLE with:

a. TM pal wun L .

! 1. Volume between 131,900 fts and 128,800 fts. !

level between +3 inches ** and -4 1/2 inches , equivalent , and a to a i

. 2. Maximum average temperature of 105'F during OPERATIONAL i

i CONDITION 1 or 2, except that the maximum average temperature may be pemitted to increase to: .

a) 110*F with THERMAL POWER less than or equal to 25 of ;

i , RATED THERMAL POWER. {

~

i b) 220*F with the main steam line isolation valves closed l

, fn11owing a , scram.

j h. D 11-to-suppre'ssion chamber bypass leakage less than'or equal to l

. of the acceptable .A/4 design value of 0.03 ft8 .

U APPLICABILITY: OPERATIONAL CONDITIONS 1, 24 and 3.

ACTION:

a.

With the suppression chamber water level outside the above limits, w

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 leastthe within HOT SWTDOW following within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . .

b.

In OPERATIONAL C0WITION 1 or 2 with the s@pression chamber average water temperature greater than or equal to 105'F, stop all testing which adds heat to the suppression peol, and restore the average

' temperature to less than or equal to 105'F within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at. least HDT SWTDOWN 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 fo1 lowing 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , except, as pemitted above:

, 1 i

~

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

2. With the sgpression. chamber average water temperature greater

> than 120*F, depressurize the reactor pressure vessel to less

. e than 200 psig within 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months .

v #see Specification 3.5.3 for ECCS requirements.

- Level is referenced to a plant elevation of 699 feet 11 inches (See Figure 8 3/4.6.2-1).

LA SALLE - UNIT 2 3/4 6-19 Amendment No. 49

. . - . _ _ . _ _ _ _ . _ _ . _ , _ _ . - _ . ~ . _ . _ _ _ _ _ _ _ _ - __ __ _ ___ _ ___

1

i I

i -

l CONTAI WENT SYSTEMS I ~ .

i LIMITING CONDITION FOR OPERATION (Continued) l ACTION: (Continued) i c.

i With one supp b on chamber. water level instrumentation channe i ' inoperable and/or with one suppression pool water temperature j

Deleimd i

instrumentation instrumentation to 0PERABLE division inoperable,ithin status w restore the inoperable 7 days er j sion chamber water level and/or temperature to be within the limits

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

~

! d.

, FWith both suppression chamber water level instrumentation channels

! inoperable and/or with both suppression puol water tamperature i

instrumentation divisions inoperable, restore at least one l inoperable water level channel and one water temper a uret 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 leastj HDT SHUT

{, 24 hothevnext 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SWTDOW within the follouin within

! e.

i With the drywell-to-suppression chamber bypass laskage in excess of

the limit, restore the bypass leakage te vithin the 'imit prior to

n. increasing reactor coolant tamperature above 200*F.

I 1 SURVEILLANCE ~ REQUIREMENTS - '

i i 4.6.2.1 The suppression chamber shall be demonstrated OPERABLE:

{ a.

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

b. s

{ At least once pe,r 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in OPERATIONAL COMITION 1 or 2 b the suppression equal chamber average water tamperature to be less than or to 105'F, except:

1. -

i ~

At least once per 5 minutes during testing which adds heat to j

7:.:..ysverage

..:w.s water. temperature less than er equal, to 1

! 2

! dt Toastonce per 50 minutes when s rossion chamber average

!' '.S water temperature is greater than 105 F, by verifying suppression i - chamber average water temperature less than or equal to 110*F 1 and POWER. THERNAL POWER less than or equal to 15 of RATED THERMAL w 4

3.

At least once 'per 30 minutes following a scram with suppression '.,

chamber 105'F, by everage ver water tamperature greatef.-than or equal to less than or equal fyingtosuppression 120*F. chamber everage water temperature

.O LA SALLE - UNIT 2 3/4 6-20

. Amendment McL. 49

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

l J

l 1 !

CONTATNMENT SYSTEMR 4

quRVETLLANCE REO'_7TREMENTS (Continuedi 1

, c.

By verifying at least two suppression chamber water level instru-mentation channels and at least 14 suppression pool water j temperature instrumentation channels. 7 in each of two divisions, OPERABLE by performance of as

, 1. CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , 2.

4 CHANNEL FUNCTIONAL TEST at least once per 31 days, and i

) 3. CHANNEL CALIBRATION at least once per 18 months.

i The suppression chamber water level and suppression pool '

temperature alarm setpoint shall be:

a) High water level 1 +2 inches

b) Low water level 7. -3 inches

c) High temperature s 105 F d.

By conducting drywell-to-suppression chamber bypass leak tests at least once per 18 months at an initial differential p'ressure of 1.5 psi and verifying that the A/[k calculated from the measured leakage is within the specified limit.

If any 1.5 psi leak test results in a calculated A/[k > 20% of the specified limit, then the test schedule for subsequent tests shall be reviewed by the Commission.

If two consecutive 1.5 psi leak tests result in a calculated A//k greater than the specified limit, then:

1.

A 1.5 psi leak test shall be performed at least once per 9 months until two consecutive 1.5 psi leak tests result in the calculated A/[k within the specified limits, and

2. A 5 psi leak test, performed with the second consecutive successful 1.5 psi leak test, results in a calculated A/[k within the specified limit, after which the above schedule of once per 18 months for only 1.5 psi leak tests may be resumed.

If any required 5 psi leak test results in a, calculated A/[k greater than the specified limit, then the test schedule for subsequent tests shall be reviewed by the Commission.

-If two consecutive 5 psi leak tests result in a calculated A/[k greater than the specified limit, then a 5 psi leak test shall be performed at least once per 9 months until two consecutive 5 psi leak tests result in a calculated A/[k within the specified limit, after which the above schedule of'once per 18 months for only 1.5 psi leak tests may be resumed.

Figure Level is referenced to a plant elevation of 699 feet 11 inches (See B 3/4.6.2-1).

LA SALLE - UNIT 2 3/4 6-21 Amendment No. 87

. 1

}

EMERGENCY CORE C00LfNG SYSTEMS BASES 3/4.5.1 and 3/4.5.2 ECCS - OPERATING and SHUTDOWN (Continued)

ADS automatically controls seven selected safety-relief valves. Six valves are required to be OPERABLE since the LOCA analysis assumes 6 ADS

, valves in addition to a single failure. It is therefore appropriate to permit i one of the required valves to be out-of-service for up to 14 days without i

materially reducing system reliability.

D 3/4.5.3 SUPPRESSION CHAMBER

{

i i

The suppression chamber is also required to be OPERABLE as part of the ECCS to ensure that a sufficient supply of water is available to the HPCS, i LPCS and LPCI systems in the event of a LOCA. This limit on suppression

chamber minimum water volume ensures that sufficient water is available to i permit recirculation cooling flow to the core (See Figure B 3/4.6.2-1). The

! OPERABILITY of the suppression chamber in OPERATIONAL CONDITIONS 1, 2 or 3 is j 9equired by Specification 3.6.2.1.

Repair work might require making the suppression chamber 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 chamber must be made' inoperable in OPERATIONAL '

CONDITION 4 or 5.

In OPERATIONAL CONDITION 4 and 5 the suppression chamber minimum required water volume is reduced because the reactor coolant is maintained at or below E00*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. i

'NSEAT

- D LA SALLE - UNIT 2 B 3/4 5-3 Amendment No. 91

ATTACl1 MENT B PROPOSED AMENDMENTS TO THE LICENSE / TECHNICAL SPECIFICATIONS i

INSERT D The ADS accumulator supply header pressure is supplied by the normal instrument nitrogen system, which has two compressors. This system supplies

, both the low pressure pneumatic supply header for other pneumatic j equipment / components in the drywell and the two high pressure ADS l accumulator supply headers. Maintaining the ADS accumulators at greater than i

or equal to 150 psig assures that the accumulators are pressurized to greater than or equal to 150 psig prior to the loss of the normal pneumatic supply. With an initial pressure of 150 psig, the accumulator is designed to operate the

safety / relief valve two times at 70% of drywell design pressure following failure of the pneumatic supply to the accumulator. TS SR 4.5.1.d.1.a assures that this l initial condition is met. The monthly frequency for this SR is adequate, because j of the reliability of the normal pneumatic supply and multiple alarms that

]' indicate the loss of the normal pneumatic supply. In addition, each ADS accumulator has a low pressure alarm in the control room which will signal

when an ADS accumulator is less than 150 psig. This monitoring surveillance

and the monthly frequency is consistent with the corresponding SR 3.5.1.3 in NUREG 1434, Rev.1.

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] The ADS accumulator backup compressed gas system is comprised of two i separate bottle banks of nitrogen bottles, one bottle bank for each high

. pressure ADS accumulator supply header. One header supplies 3 ADS valve j accumulators, the other header supplies the remaining 4 ADS valves. Each I

! bank of the ADS accumulator backup compressed gas system has its own l indication and alarm for low pressure. This is a backup system provided for long term availability of ADS during and following an accident and therefore is required to be Operable. The monitoring surveillance assures the continued l Operability of ADS. The monthly frequency for this SR is adequate, because i each ADS bottle bank has a low pressure alarm. Also, unless the normal l pneumatic supply is lost, the only losses from the bottles is through gas

! leakage, which is minimal.

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ATTACHMENT B I

PROPO9ED AMENDMENTS TO THE LICENS.. ?CHNICAL SPECIFICATIONS i

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INSERT D(continued)

Action statement k, for the ADS accumulator backup compressed gas system bottle pressure less than 500 psig, is adequate, because this is a backup system to the ADS valve accumulators. The allowed outage time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is reasonable based on the ADS valve accumulators remaining greater than 150 j psig, belcri which the associated ADS valves are inoperable. In addition, the 72

hours provides sufficient time to obtain full nitrogen bottle (s) and replace low i l pressure bottles with the full bottle (s).

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3 ATTACHMENT C i SIGNIFICANT HAZARDS CONSIDERATION i

i The changes involve the Surveillance Requirements of five TS concerning indicators / alarms that have no corresponding Action statements if the indication i

and/or alarms are not Operable. The instrumentation has no automatic or

interlock type functions. These TS involve Surveillance Requirements (SRs) 4.1.3.5.b, 4.4.3.2.1, 4.5.1.d.1, 4.5.1.d.2.c), 4.5.3.1.b, and 4.6.2.1.c.3. These TS SRs, or portions of the TS SRs, are proposed to be relocated, rather than changed,

! because they are not required to be in the TS by any of the four criteria in l 10CFR50.36(c)(2)(ii) and are not in NUREG 1434, Standard Technical

Specifications.

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( Commonwealth Edison has evaluated the proposed Technical Specification l Amendment and determined that it does not represent a significant hazards

! consideration. Based on the criteria for defining a significant hazards l consideration established in 10 CFR 50.92, operation of LaSalle County Station l Units 1 and 2 in accordance with the proposed amendment will not:

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

i The proposed change relocates instrumentation requirements, which i provide no post-accident function from the Technical Specifications to the jr Bases, UFSAR, procedures, or other plant controlled documents. These

, requirements are part of routine operational monitoring and are not l considered in the safety analysis. The Bases, UFSAR, procedures, and j other plant controlled documents containing the relocated information will be maintained in accordance with 10 CFR 50.59. In addition to 10 CFR ;

i 50.59 provisions, the Technical Specification Bases are subject to the ;

j change control provisions in the Administrative Controls Chapter of the j Technical Specifications. The UFSAR is subject to the change control l provisions of 10 CFR 50.71(e), and plant procedures and other plant j controlled documents are subject to controls imposed by plant i administrative procedures, which endorse applicable regulations and

{ standards. Since any changes to the Bases, UFSAR, procedures, or other l plant controlled documents will be evaluated per the requirements of i 10CFR50.59, no significant increase in the probability or consequences of 4 an accident previously evaluated will be allowed. Therefore, this change does not involve a significant incmase in the probability or consequences j of an accident previously evaluated.

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ATTACHMENT C SIGNIFICANT HAZARDS CONSIDERATION The Reactor Coolant Operational Leakage limits monitoring surveillanco 4.4.3.2.1 has been modified to eliminate procedural details of what instrumentation / leakage detection systems to use in verifying limits. The proposed surveillance requires verification that the reactor coolant system leakage is within limits at the same frequency as the current surveillance requirement. The reactor coolant leakage detection systems operability requirements are controlled by Technical Specification ,

3/4.4.3.1. Since any changes to procedures describing the method of l monitoring leakage will be evaluated per the requirements of 10CFR50.59, i no significant increase in the probability or consequences of an accident previously evaluated will be allowed. Therefore, this change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

The monitoring action and the surveillance requirements added for the ;

Automatic Depressurization System (ADS) pneumatic supply help assure the continued operability of ADS for the mitigation of accidents involving high reactor vessel pressure and the loss of the high pressure core spray system. The surveillance frequency is reasonable for the ADS supply header pressure due to the redundancy of the instrument nitrogen ;

system, several alarms warning of system trouble. The ADS accumulator l backup compressed gas system bottle pressure monitoring surveillance '

frequency and the proposed action on low bottle pressure is reasonable due to the ADS accumulator clieck valves and the normal ADS supply header. Therefore, this change does not involve a significant increase in ;

the probability or consequences of an accident previously evaluated.

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2) Create the possibility of a new or different kind of accident from any !

accident previously evaluated because:

The proposed change does not involve a physical alteration of the plant (no new or different type of equipment will be installed) or a change in the methods governing normal plant operation. The proposed change will not impose or eliminate any requirements, and adequate control of the requirements will be maintained. Thus, these changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.

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ATTACHMENT C SIGNIFICANT HAZARDS CONSIDERATION

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

1 The proposed change will not reduce a margin of safety because it has no impact on any safety analysis assumption. In addition, the requirements to be transposed from the Technical Specifications to procedures, or

! other plant controlled documents are the same as the existing Technical l

Specifications. Since any future changes to these requirements in the Bases, UFSAR, procedures, or other plant controlled documents will be evaluated per the requirements of 10 CFR 50.59, no significant reduction in a margin of safety will be allowed.

Based on 10 CFR 50.92, the existing requirement for NRC review and approval of revisions to these requirements proposed for relocation, does not have a specific margin of safety upon which to evaluate. However, since the proposed change is consistent with the BWR Standard Technical Specifications, NUREG-1434, approved by the NRC Staff, revising the Technical Specifications to reflect the approved level of instrumentation requirements ensures no significant reduction in the margin of safety.

The Reactor Coolant Operational Leakage limits monitoring surveillance 4.4.3.2.1 has been modified to eliminate procedural details of what instrumentation / leakage detection systems to use in verifying limits. The proposed surveillance requires verification that the reactor coolant system leakage is within limits at the same frequency as the current surveillance requirement. The reactor coolant leakage detection systems operability requirements are controlled by Technical Specification 3/4.4.3.1. Because there are no changes to either the reactor coolant leakage detection systems and the reactor coolant leakage continues to be maintained within the specified limits, at the required frequency, there is no reduction in the margin of safety.

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ATTACHMENT C SIGNIFICANT HAZARDS CONSIDERATION The monitoring action and the surveillance requirements added for the Automatic Depressurization System (ADS) pneumatic supply help assure the continued operability of ADS for the mitigation of accidents involving high reactor vessel pressure and the loss of the high pressure core spray system. This helps assure ADS is maintained in a ready status. The previous TS SRs only tested the instrumentation, and did not verify the parameter remained within limits. Therefore, with the margin of safety is not reduced.

Guidance has been provided in " Final Procedures and Standards on No Significant Hazards Considerations," Final Rule,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 which are and are not considered likely to involve significant hazards considerations. These proposed amendments most closely fit the example of a change which may either result in some increase to the probability or consequences of a previously analyzed accident or may reduce in some way a safety margin, but where the results of the change are clearly within all acceptable criteria with respect to the system or component specified in the Standard Review Plan.

This proposed amendment does not involve a significant relaxation of the criteria used to establish safety limits, a significant relaxation of the bases for the limiting safety system settings or a significant relaxation of the bases for the limiting conditions for operations. Therefore, based on the guidance provided in the Federal Register and the criteria established in 10 CFR 50.92(c), the proposed change does not constitute a significant hazards consideration.

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l ATTACHMENT D ENVIRONMENTAL ASSESSMENT STATEMENT APPLICABILITY REVIEW l.

Commonwealth Edison has evaluated the proposed amendment against the i

criteria for identification of licensing and regulatory actions requiring environmental assessment in accordance with 10 CFR Part 51.21. It has been j determined that the proposed changes meet the criteria for categorical exclusion as provided for under 10 CFR Part 51.22(c)(9). This conclusion has

been determined because the changes requested do not pose significant i hazards considerations or do not involve a significant increase in the amounts,

! and no significant changes in the types of any effluents that may be released i

off-site. Additionally, this request does not involve a significant increase in

individual or cumulative occupational radiation exposure.

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ML20134A193

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