Text

Proposed Tech Specs,Lowering Power Level Below Which TCV & TSV Closure Scram Signals & EOC-RPT Signal Are Not in Effect
	ML20154M464
Person / Time
Site:	LaSalle
Issue date:	10/16/1998
From:	; COMMONWEALTH EDISON CO.
To:	;
Shared Package
ML20138L307	List: ML20154M455; ML20154M464;
References
	NUDOCS 9810200300
	Download: ML20154M464 (52)
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l ATTACHMENTB LASALLE COUNTY STATION MARKED UP ANNOTATED COPY OF AFFECTED PAGES FOR PROPOSED CHANGES TO FACILITY OPERATING LICENSES NPF-11 AND NPF-18 '

l APPENDIX A TECHNICAL SPECIFICATIONS I l

l l

9810200300 981016*

PDR ADOCK 05000373 P pg l

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i ATTACHMENT B TECHNICAL SPECIFICATION CHANGES FOR LASALLE UNITS 1 & 2

SUMMARY

OF AFFECTED PAGES FOR LASALLE UNITS 1 & 2 NPF-11 NPF-18 3/4 3-2* 3/4 3-2*

3/4 3-3* 3/4 3-3*

3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 3/4 3-7* 3/4 3-7*

3/4 3-8 3/4 3-8 INSERT A INSERT A 3/4 3-39 3/4 3-39 3/4 3-40 3/4 3-40*

3/4341 3/4341 3/4344 3/4344 INSERT B INSERT B B 3/4 3-3 8 3/4 3-3

These pages are provided for continuity only and have no proposed changes, i

B-1

SUMMARY

OF PROPOSED CHANGES FOR LASALLE UNITS 1 & 2 (NPF-11 & NPF-18) ,

1 4

Table 3.3.1-1 Action #6 is revised to reflect the new bypass setpoint for ,

TCV and TSV closure scram signals. The value of thermal l power is changed and reference to turbine first stage pressure I is deleted.

Table 3.3.1-1 Table Notation (i) is revised to reflect the new bypass setpoint for TCV and TSV closure scram signals. The value for thermal l power is changed and reference to turbine first stage pressure !

is deleted. In addition, the table notation is reworded to state that the scram signals shall not be automatically bypassed when THERMAL POWER is greater than or equal to 25% of rated thermal power.

Table 4.3.1.1-1 Note (i) has been added to the TCV and TSV closure scram trip functions to require verification once per 18-months that Turbine Stop Valu- - Closure and Turbine Control Valve Fast Closure Valve Tnp System Oil Pressure - Low Trip Functions are not bypassed when THERMAL POWER is > 25% of RATED THERMAL POWER. Specification 4.0.2 applies to this 18-month intental.

Section 3.3.4.2 The Applicability and Action statements are revised to reflect the new bypass setpoint for EOC-RPT signals. Values for thermal power are changed.

Table 3.3.4.2-1 Footnote (b) is revised to reflect the new bypass setpoint for TCV and TSV closure scram signals. The values for thermal power are changed and reference to first stage turbine pressure

are deleted. In addition, the footnote is reworded to state that the scram signals shall not be automatically bypassed when i THERMAL POWER is greater than or equal to 25% of rated thermal power.

3

! B-2 i

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Table 4.3.4.2.1-1 Note (a) has been added to the TCV and TSV closure scram trip functions to require verification once per 18-months that Turbine Stop Valve - Closure and Turbine Control Valve Fast Closure Valve Trip System Oil Pressure - Low Trip Functions are not bypassed when THERMAL POWER is > 25% of RATED THERMAL POWER. Specification 4.0.2 applies to this 18-month interval.

Bases Section This section is revised to reflect the new bypass setpoint for 3/4.3.4 EOC-RPT signals. The value for thermal power is changed.

B-3

~

TABLE 3.3.1-1 i REETOR PRDTECT1011 SYSTEM INSTRtRHTATION APPLICABLE MINiftflOPERABLE.

P OPERATIONAL CMAltlELS PER FINICTIONAL IMIT ColWITI0llS !

TRIP SYSTEM fa) . ETION

1. Intermodlate Range Monitors:

i

a. Ilestron Flux - High 2 3 1 -

3 4 2 2 S'b !

3 3

b. Insperative 2 3 I 3, 4 2 2 i

5- 3 3 *

2. Average Power Range Moniter i

a. lieutron Flux - High, Setdown- 2 2 1 3 2 2 5* 2 t

b. Flow Blased $1mulated Thenmal 3

%y o

i Power-Upscale ~ I o 2 4 7

c. Fixed Ileutron Flux-High O p 1

\ 5~

2 4 $a

-+ r l

d. Insperative 1. 2 3

5 2

2 1

2 5'$

E- u i

2 3

3. Reacter Vessel Steam Dome X*c3 Pressure - High 1, 2

1 ON 2 1 1 5' I

4. Reacter Vessel Water Level - Low, Level 3 Y DA 1, 2 2 1

5. Main Steam Line Iselatten Valve -

Closure l 4 , 4

6. DELETED LA SALLE - UlllT 1 3/4 3-2 heendment No. l'15 .

I TABLE 3.3.1-1 (Continued) 9 !

u. REACTOR PROTECTION SYSTEM INSTRimENTATION !

p. !

. !;; APPLICA8LE MININUM OPERA 8LE OPERATIONAL CHANNELS PER i g FUNCTIONAL UNIT . C0lWITIONS TRIP SYSTEM (a) ACTION

7. Primary Containment Pressure - High 1, 2 II}

2 II) I i

8. Scram Discharge Volume Water-

, Level - High ly, 2 1 5 [

2 3

9. Turbine Stop Valve - Closure I III 4 III 6

~

r

10. Turbine Control Valve Fast closure, ;

Valve Trip System 011 Pressure - Low I II) 2 III 6 i pg j

$ 11. Reactor Mode Switch Shutdown I w

J, Position 1, 2 3, 4 1

1 I

7 hD 3 7 j

i

'1 2. Manual Scram 5

1, 2 1 3

{

f2$ 3b i j

i 1 1

g 3, 4 8 5-1 1 9 Ib W g ;

' t

13. Cdntrol Rod Drive O%

a. Charging Water Header 3 g -

2(h) ~ k. <A

~

I Pressure - Low 5 2 3 ;

b. Delay Timer 2 2 1 S

Ih} 2 3 SL j

=

k t a i

. .I i i

. l k

4

I ,

4 1

l l TABLE 3 4.1-1 (Continued)

4 i REACTOR PROTECTION SYSTEM.IMSTRUMENTATION I

ACTION ACTION 1 - Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 2 - Verify all insertable control rods to be inserted in the core and lock the reactor mode switch in the Shutdown position within l one hour.

ACTION 3 - Suspend all operations involving CORE ALTERATIONS

and insert all l insertable control rods within one hour.

ACTION 4 - Be in at least STARTUP within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 5 - Deleted

ACTION 6 - initiate a reduction in THERMAL POWER within 15 minute nd reduce i C.urhina first staan nro u nre to s 140 psis, equivalent 197 THERMAL '

IWE less than- ^~ ?'"ED THERMAL PUWER, Within Z hours.

ACTION 7 - Verify all insertab trol rods to be inserted within I hour.

ACTION 8 - Lock the reactor mode switch in the Shutdown position within I hour.

ACTION 9 - Suspend all operations involving CORE ALTERATIONS,* and insert all insertable control rods and lock the reactor mode switch in the SHUTDOWN position within I hour.

Except movement of IM, SM or special movable detectors, or replacement of LPM strings provided SM instrumentation is OPERA 8LE per Specification 3.9.2.

LA SALLE - UNIT 1 3/4 3-4 Amendment No. 115 ..

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

\

TAntr 3.1.1-1 (Continued)

REAf* TOR PRO'!TLaTION RYETEM TNETRUMEN"'ATTON TABLE MOTATIONS (a) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required at surveillance without placing the channel in the tripped condition l provided monitoring least one OPERABLE channel in the same trip system is that parameter. .

(b) The ' shorting links

shall be removed from the RPS circuitry prior to and during the time any control rod is withdrawn

and during shutdown margin demonstrations performed per specification 3.10.3.

(c) An APRM channel is inoperable if there are less than 2 LPRM inputs per level or less than 14 LPRM inputs to an APRM channel.

(d) This function is not required to be OPERABLE when the reactor pressure vessel head is unbolted or removed per Specification 3.10.1.

(e) This function shall be automatically bypassed when the reactor mode switch is not in the Run position.

(f) This function is not required to be OPERABLE when PRIMARY CONTAINMENT INTEGRITY is not required.

(g) Also actuates the standby gas treatment system.

With any control rod withdrawn. Not applicable to control rods removed per 60t (hl Specification 3.9.10.1 or 3.9.10.2.

3 (i) l This function grressure is's shall 140 psig, be autoestically bypassed when furbine first sta e '

THERMAL POWER. equivalenstsPTHERMALPOWERgessthan30% TED (j) Also actuates the EOC-RPT system.

ib h I'O d d P t R h wepl6 2rp.

I l

Not required for control rods removed per Specifications 3.9.10.1 or 3.9.10.2.

LA SALLE - UNIT 1 3/4 3-5 Amendment No. 104

r

, TABLE 4.1.1.1-1 REACTOR Heittilm SYSTEN IntT!!La!ENTATION SWVEILLAurr armIIE::[gTS -

CHAMEL OPERATIONAL CHAMEL FUNCTIOML CHAMEL F MCTlWAL IIllT COWIT10NS FOR WICH l CHFtr TEST CALIBRATION"' SURVFILLANCE REOUIRED i

1. Intermediate Range Monitors i

s. Noetron Flux - Nigh $/U"',5 S/tf**, W ,

R 2*

5 W R 3*, 4, 5

b. Insperative m W . NA 2*, 3*, 4, 5 2.-

Average Feuer Range Noniter:"'

a. Neutron Flux - High, t

Setdeun ~S/U"',5 S/tf*8, W SA 2* l 5

b. Flow Blased Simulated Thennal W SA 3*, 5 pg

, o i

Power-Upscale S D'* S/tf*', Q W'*"', SA, R*' !

c. I oo n Flued Neutron Flux - !

Migh 5 S/U"8,Q W'*, d *

d. Insperative m Q NA SA 1 1, 2, 3, 5 l kn gd i

3. Reactor Vessel Steam Dome

ts t Pressure - High M Q -

Q 1, 2 5m X L i

4. Reacter Vessel Water Level - 0%

Low, Level 3 l 3 NA Q R 1, 2 .

b Y. g l

(

5. Main Steam Line Isolatten Valve - Closure m Q R I b

A

6. Deleted

7. Primary Containment Pressure -

High M Q Q 1, 2- [

i i

I LA SALLE - WIT 1 3/4 3-7 hnt No. -115 !

s' !

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

y. - m. . _ . _ . . _ .-

l TABLE 4.J.1.1-1 (Centinued)

REACTOR FEuim.m_-TION SYETEM INST *L*MNTATION SURVRI 3 mg menesta_.__ a

f. CHAINSEL OPERATIONAL TUNCTIONAL UNIT (g} CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICM -

CHECK TEST CALIBRATION SURVEILLANCE REOUIRED i

8. Scram Discharge volume Nater !

Level - High NA Q R 1, 2, 5

9. Turbine stop valve - Closur NA Q R 1

10. Turbine Control Valve Fast Closure Valve Trip System Oil Pressure - Low , [

NA Q R 1

11. Reactor Mode Switch Shutdown Position NA R NA 1,2,3,4,5

12. Manual Scram NA I

N NA 1, 2, 3, 4, 5

13. Control Rod Drive

a. Charging Water Header Pressure - Low NA M R 2, 5 ;

b. Delay Timer NA M R 2, 5 t l

tal Neutron detectors may be excluded from CHANNEL CALIBRATION.

(b) The IRM and SRM channels shall be determined to overlap for at least 1/2 decades during each startup and the IRM and APRM channels shall be determined to overlap for at least 1/2 decades during each controlled l shutdown, if not performed within the previous 7 days.

(c) Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to startup, if not performed within the previous 7 days. !

Idl This calibration shall eenstat of the adjustment of the APRM channel to conform to the power levels calculated by a heat balance during OPERATIONAL CONDITION 1 when THERNAL PONER at 25% of RATED THERMAL POWER. The APRM Gain Adjustment Factor (GAFI for any channel shall be equal to the power value deter-mined by the heat balance divided by the APRM reading for that channel. l i

Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , adjust any APRM channel with a GAF > 1.02. In addition, adjust any APRM channel within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , it power is greater than or equal to 90% of RATED THERMAL PONER and the APRM channel CAF is l t

< 0.98. Until any required APRM adjustment has been accomplished, notification shall be posted on the reactor control panel. t P

le) This calibration shall consist of the adjustment of the APRM flow biased channel to conform to a calibrated flow signal.

(f) The LPRMs shall be calibrated at least once per 1000 effective full power hours (EFPHl. l (g) Measure and compare core flow to rated core flow.

th) This calibration shall consist of verifying the 6 3. 1 second simulated thermal power time constant.

The provisions of Specification 4.0.4 are not applicable for a period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after entering '

OPERA *IONAL CONDITION 2 or 3 when shutting down from OPERATIONAL CONDITION 1.

[

i

} '

s INSERTA :

d LA SALLE - UNIT 1 3/4 3-8 Amendment No. 104

t -

INSERT A (i) At least once per 18 months, verify Turbine Stop Valve - Closure and Turbine Control Valve Fast Closure Valve Trip System Oil Pressure - Low Trip Functions are not bypassed when THERMAL POWER is > 25% of RATED -

THERMAL POWER. Specification 4.0.2 applies to this 18-month interval.

I B-4

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

INETRUMENTATTON d- ENn-OF-cycf.F RrcTRetfLATT ON Pt1MP TR T P EYETEM TNETRtfMENTATTON j LYMITTNO CONDTTION FOR OPERATION 3.3.4.2 The end-of-cycle recirculation pump trip (EOC-RPT) system instrumentation channels shown in Table 3.3.4.2-1 shall be OPERABLE with their trip setpojnts set consistent with the values..shown in the Trip Setpoint i column of Table 3.3.4.2-2 and with tho'END-OF-CYCLE RECIRCULATION PUMP TRIP l SYSTEM RESPONSE TIME as shown in Table 3.3.4.2-3. , i APPLTCAETLTTY: OPERATIONAL CONDITION 1, when THERMAL POWER is greater than or equal t RATED THERMAL POWER.

1 ACTION:

a. With an'and-of-cycle recirculation pump trip system instrumentation ;

channel trip setpoint less conserva*1ve than the value shown in the '

Allowable values column of Table 3.3.1.2-2, declare the channel inoperable until the channel is reveled to OPERABLE status with the channel setpoint adjusted consistent with the Trip Setpoint value. ;

b. With the number of OPERABLE channels one less than required by the j

Minimum OPERABLE Channels per Trip system requirement for one or-both trip systems, place the inoperable channel (s) in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

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

, 1. If the inoperable channels consist of one turbine control valve channel and one turbine step valve channel, place both inoperable channels in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

, 2. If the inoperable channels include two turbine control valve channels or two turbine stop valve channels, declare the trip )

system inoperable. ;

I

d. With one trip system inoperable, restore the inoperable trip system l to OPERABLE status within '12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Otherwise, either:

4

1. Increase the MINIMUM CRITICAL POWER RATIO (MCPR) Limiting Condition for operation (LCol to the EOC-RPT inoperable value per Specification 3.2.3 within the next 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or,

2. Reduce THERMAL POWER to less than RATED THERMAL POWER.

within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

e. With both trip systems inoperable. restore at least one trip system to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . Otherwise, either:

I f ,

i l

4 LA SALLE - UNIT 1 3/4 3-39 Amendment No. 104

,4 . . , , . , _. - . . .

M i

1 L

INSTRUMENTATION END-OF-CYCLE RECIRCULATION PUNP TRIP SYSTEM INSTRUMENTATION

[ LIMITING CONDITION FOR OPERATION

! 1. Increase the MINIMUM CRITICAL POWER RATIO (MCPR) Limiting

Condition for Operation (LCO) to the E0C-RPT inoperable value per Specification 3.2.3 within the next I hour or,

2. reduce THERMAL POWER to less than M of RATED THERMAL POWER 1 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

2.5 o h*

i SURVEILLANCE REOUIREMENTS j 4.3.4.2.1 Each and-of-cycle recirculation pump trip system instrumentation l- channel shall be demonstrated OPERABLE by the performance of the CHANNEL

~ FUNCTIONAL TEST and CHANNEL CALIBRATION operations at the frequencies shown in i Table 4.3.4.2.1-1.

4.3.4.2.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

4.3.4.2.3 The END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME of !

each trip function shown in Table 3.3.4.2-3 shall be demonstrated to be within l its limit at least once per 18 months. Each test shall include at least the i i logic of one type of channel input.. turbine control valve fast closure or i- turbine stop valve closure, such that both types of channel inputs are tested ,

at least once per 36 months. The time allotted for breaker are suppression !

3 shall be verified by test at least once per 60 months. '

N, E

4 t

5

.l -

! )

a LA SALLE - UNIT 1 3/4 3-40 Amendment No. 94 y j- _ . - . . e .

- - . ., -. . = . - .

w

+

TABLE 3.3.4.2-1 .

mean.0F-cYcrm macraci;;.syrnes pw p Tarp gig - g__,_ __,_;fon

i MININUM OPERABLE CHANNELS TRIP FUNCTION PER TRIP SYSTEMI *I i

1. Turbine Stop Valve.- Closure 2tbl

2. Turbine Control Valve - Fast closure 2tbl i

i i

not .

tal A trip system may. be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided that the 4ther trip system is OPERABLE.

p l' ,

(b) This function shalP be automatically bypas_ sed whenfturbine first staae pressure is less than or equal) -

ho140psig, equivalent tj THERMAL POMER Sess than 309 of RATED THERMAL PGWER.

k b isg re,6,.tf, o"Spalfo.zs2 i

L i.

t

[

t

-[

I

.a nat.t.F: - UNIT 1 3/4 3-41 Amendment No.104 ' !

i

i J ._ .

TA8il: 4 3.4.2.1-1 LM1-OF-CYCLE RECIRCUI AlllM PUNP ikiP SYSifM SURVElllANCE REQUIREMENTS CHANNEL i v.

FUNCT10NAL CHANNEL

~

S TRIP FUNCTION @) TEST CALIBRATioli Turbine stop Valve-Closur l

b 1. Q R c*

2. Turbine Control Valve-Fast Closure

( Q R l

t w

w i:

R 5

iR a

c INSERTB 4

P INSERT B l

(a) At least once per 18 months, verify Turbine Stop Valve - Closure and Turbine p ControlValve_- Fast Closure Trip Functions are not bypassed when L

THERMAL POWER is > 25% of RATED THERMAL POWER.- Specification 4.0.2 applies to this 18-month interval.

l L

1 i

i 1

B-5

2NSTRtfMENTATTON mAsrs 3/4_3_d RTETREffLATTON PtfMP TRTP AETifATION TNRTRIJMEWFATION The anticipated transient without scram (ATWS) recirculation pump trip system provides a means of limiting the consequences of the unlikely occurrence of a failure to scram during an anticipated transient. The !

response of the plant to this postulated event falls within the envelope of study events in General Electric Company Topical Report NEDO-10349, dated March 1971 and NEDO-24222, dated December, 1979, and, Appendix G of the FSAR.

The end-of-cycle recirculation pump trip (EOC-RPT) system is a part of the Reactor reactor Protection trip. system and is an essential safety supplement to the The purpose of the EOC-RPT is to recover the loss of thermal margin that which occurs at the end-of-cycle. The physical phenomenon involved is '

the void reactivity feedback due to a pressurization transient can add positive reactivity to the reactor system at a faster rate than the control roda add negative scram reactivity. Each EOC-RPT system trips both recircula-tion pumps, reducing coolant flow in order to reduce the void collapse in the core during two of the most limiting pressurization events. The two events l for which the EOC-RPT protective feature will function are closure of the turbine stop valves and fast closure of the turbine control valves.

A generic analysis, which provides for continued operation with one or both trip systems of the EOC-RPT system inoperable, has been performed. The analysis determined bounding cycle independent MINIMUM CRITICAL POWER RATIO (MCPR) Limiting Condition for Operation (LCO) values which must be used if the EOC-EPT system is inoperable. These values ensure that adequate reactivity l margin with theto thefunction RPT MCPR safety limit exists in the event of the analyzed transient inoperable.

I in the bases for specification 3.2.3. The analysis results are further discussed A fast closure sensor from each of two turbine control valves provides i

! T input to the EOC-RPT systems a fast closure sensor from each of the other two f turbine control valves provides input to the second EOC-RPT system.

similarly, a position switch for each of two turbine stop valves provides )

input to one EOC-RPT systear a position switch from each of the other two stop valves providas input to the other EOC-RPT system. For each EOC-RPT system, the sensor relay contacts are arranged to form a 2-out-of-2 logic for the fast closure of turbine control valves and a valves. 2-out-of-2 logic for the turbine stop The operation of either logic will trip both recirculation pumps.

actuate the EOC-RPT system and Each EOC-RPT system may be manually bypassed by use of a keyswitch which is administratively controlled.

Operating Bypass at less than The manual bypasses and the automatic the control room. ED THERMAL POWER are annunciated in specified surveillance intervals an surveillance and maintenance outage times have been determined in accordance with the following:

1.

NEDC-30851P-A,

Technical Specification Improvement Analyses for BWR Reactor Protection system *, March 1988.

i l

! )

l .J LA SALLE - UNIT 1 B 3/4 3-3 Amendment No. 104 l

TABLE 3.3.1-1 REACTOR pro 1ECTION SYSTEM INSTE!MEllTATION !

APPLICABLE MINiltlM OPERA 8LE FIRETIGRAL UlilT

' OPERATIONAL CHAfWlELS PER I i ColEITIONS TRIP SYSTEM fal ACTION

1. Intermediate Range Monitors:

a. Neutron Flux - High 2 3 1 3 4 2 i S'b 2 l 3 3 '

b. Inoperative 2 i 3 1 3, 4 ~2 2 l 5 ;

. 3 3 . t.

2. Average Power Range Moniter:

a. Neutron Flux - High, Setdown 2 2 1 pg !

3 .

26 2 2

,o ;

5' 2 3 D0 b.

Flow Blased Simulated Thermal Power-Upscale $r 1 2 4 y-[5 I

c. Fixed Neutron Flux-High 1 i 30 2 i 4 L R *f

d. Inoperative 1, t 3

2 1 l f~$

Xg 2 i 5 2 2

3 g7D !

3. Reacter Vessel Steam Dome Q 5- l Pressure - High 1 , 2'd' 2 1

hA I i

4. Reactor Vessel Water Level - Low, :

Level 3 1, 2 !

2 1 '

5. Mala steam Line Iselation Valve - - !

Closure l

4 ,

4

6. DELETED LA 5ALLE - UNIT 2 3/4 3-2 ,

Amendment No. J m t t I

No chan e prov.;deob for cont?nas!ty omy.

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s.

SE

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g,a

.g

= == .

= == --- --- == == ,

i 5

s]

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-} I ntEsig

,B5c e isx --

-e. =- =- .

.s. s.

g l-. . . .

Q 3 E,i.

, a l

4 d S.

i c a

3 c

=.

g .: s! ,H,

.- .9+. .1Ta .

, e -5 1 1 ;n.,

I ,- rg c g -

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x -

e .a lk a 1 ts 2- s

- -- . 3 i A 4 4 dd d' d d LA'54LLE - UNIT 2 3/4 3-3 Amendment No. 6 e- - - , - - , . .

4 TABLE 3.3.1-1 (Continued)

REAGTOR PROTECTION SYSTEM INSTRUNENTATION ACTION STATEMENTS ACTION I -

8e in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 2 -

Verify all insertable control rods to be inserted in the core 4

and lock the reactor mode switch in the Shutdown position within I hour.

i ACTION 3 -

Suspend all operations involving CORE ALTERATIONS

and' insert all insertable control rods within one hour.

ACTION 4 -

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

4 ACTION 5 -

DELETED ACTION 6 -

Initiate a reduction in THERMAL POWER within 15 minutes and N reduce Eurbine first stace pressure to <140 nsia. nouivalent tali)

THERMAL POWER less than TEIT THERMAL POWER, within j 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , g

ACTION 7 -

Verify all inser a le contr to be inserted within I hour.

ACTION 8 -

Lock the reactor mode switch in the Shutdown position within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . l ACTION 9 -

Suspend all operations involving CORE ALTERATIONS,* and insert all insertable control rods and lock the reactor mode switch in the SHUTDOWN position within I hour.

Except movement of IRM, SRM, or special movable detectors, or replacement of LPRM strings provided SRM instrumentation is OPERA 8tE per Specification 3.9.2.

LA SALLE'- UNIT 2 3/4 3-4 Amendment No. 100

l :

vast, s.3.1 1 (continued)

REACTOR PROTEcTTON EYSTEM TNRTRtfM5"NTATION TABLE NOTATIONS (a) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required. surveillance without placing the channel in the tripped condi- l tion provided at least one OPERABLE channel in the same trip system is monitoring that parameter.

(b) The " shorting links" shall be removed from the itPS circuitry prior to and

.during the time any control rod is withdrawn

and during shutdown margin

' demonstrations performed per specification 3.10.3.

(c) An APRM channel is inoperable if there are less'than 2 LPRM inputs per level or less than 14 LPRM inputs to an APRM channel.

(d) This function is not required to be OPERABLE when the reactor pressure vessel head is unbclted or removed per Specification 3.10.1. j

.(e) This function shall-be automatically bypassed when the reactor mode switch is not in the Run position.

.(f) This function is not required to be OPERABLE when PRIMARY CONTAINMENT INTEGRITY is not required.

(g) Also actuates the standby gas treatment system.

h) With any control rod withdrawn. Not. applicable to conh.rol rods removed per specification 3.9.10.1 or 3.9.10.2.

,*p I 1

) This function shall'be automatically bypassed when urbine first sta l (pre KATED_ssure THr.isanal i 140 N psig, r.a.

equivalent t_3 THERMAL POWERN ess than 30

~

(j) Also actuates the EOC-RPT system.

g3 h or ual to152 Not required for control rods removed per Specification 3.9.10.1 or 3.9.10.2.

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l LA SALLE - UNIT 2 3/4 3-5 Amendment No. 90

i TABLE 4.3.1.1-1 REACTOR PRDTECTION SYSTEM i::STERENTATION SURVEILLAHCE REGUIRElENTS s

CHAlglEL OPERATIOML i CHA181EL FullCTIOML CMMNEL~

TullCTIMAL Ulili COMITIONS FOR WICH

. CHECll TEST CAtlii::ATig(a) SURVEILLANCE REGUIRED

1. Intermediate Range Monitors

a. Heutron Flux - High S/U'",5 S/U"', W R 2* 1 S W

b. Insperative.

R 3*, 4, 5 i M V M 2*, 3*, 4, 5

2. Average Feuer Ruge Moniter:"'

a. Neutron Flux - High,

setdeun s/u"8 s s/u"), W S W sa SA 2*

3*, 5 g

b. Flow Blased $1mulated Thermal l 0o 5

i Power-Upscale s, D 48 s/U'**, q N'*"* , sA, R"'

LnaOP$ '

1

c. Fixed Heutron Flux - f '

High 5 5/u"', q N'*, 3 SA

d. Insperative E 1

$ l

- Q R 1, 2, 3, 5 (

f3 a b4

3. 1 Reacter Vessel Steam Dome EM 4.

Pressure - High M q q 1, 2

%q !

Reactor Vessel Water Level -

Low, level 3 5 g Od R -

1, 2 5- 1

5. Main steam Line Isolatten Valve - Closure (M[9--- i i m q R 1 i

6. DELETED '

i i

7. Primary Centainment Pressure - I High M q q 1, 2 ;

r LA SALLE - UNIT 2 3/4 3-7 Amendment No.100 ; .

_ _ _ _ . _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _________.___~

TAllLEA11M (Continisodi >

REACTOR _l'ROTECTIOff. SYSTt2LiffSTRUtlLIffAT10ft EURVEILLANCE_REQlllREllElffS j

. CitANNLt. OPERATIONAL CHANNEI. FtINCTIONAI. CHANNEL CONDITIONS FOR NHICH EUNCTlDit&L lltflT (L . CllEClk TEST.__ CALIBRATION EHRYEILLANCE REoUIRED l

, 8. Scram Discharge Volume watus g 6 Level - High NA 0 R 1 2 5 I

9. Turbine stop valve - Closus MA U R 1

10. Tushine Constrol Valve Fast Closure Valve Trip System Oll; '

Pressure - Lo NA O R 1 Reactor Mode Switch 11.

Shutdown Position NA R NA 1. 2 3. 4 5 .

12. Manual Ecran NA W NA 1. 2 3. 4. 5

13. Control find Drive

a. Charging Water Header Pressute - Low NA M R 2 5 .

b. Delay Timer NA M .R 2 5 tal Neutron detectors may be escluded from CHANNEL CALIBRATION.

Ibl The aftM and SRM channels shall be determined to everlap for at least 1/2 decades during each startup ,

and the IRM and ArleM ehanneta shall he determined to everlap for at least 1/2 decades during each een- ,

trolled shutdown. If not performed within the previous 7 days. ;

tel Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to startup. If not performed wit hin the previous 7 days.

idl This calibration shall constat of the adjustment of the APRM channel to conform to the power levels calculated by a heat balance sharing OPERATIONAL CONDITION 1 when THERMAL POwtR a 25% of RATED THERMAL I'ONER . The APRM Gain Adjustment Factor IGAF) for any channel shall be equal to the power value deter- l mined by the beat balance divided by the APRM reading for that channel. :

i within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , adjust any APRM channel with a GAF > 1.02. In addition, adjust any APRM channel within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . If power is greate than or equal to 90% of RATED THERNAL PONER and the APRM channel GAF is

< 0.98. Until any required APRM adjustment has been accomplished.-notification shall be posted on the seactor control panel.

tel This calibration shall cons tat. of t he adjustment of the APRM flow himsed channel to conform to a callbtated flow stenal.

Ifl The LPRMs shall be calibrated at least once per 1000 effective full power hours (EFPHl.

Igl Measure and compare cores flow to rated cure fluw.

th) This calthration shall cotisist of verifying the 6 1 1 second simulated thermal power time constant. i i

The provisions of Specification 4.0.4 are not applicable for a period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after entering OPERATIONAI CONDITION 2 or 1 when shutting down from OPERATIONAL CONDITION 1.

lNSERT A ;

i LA SALLE - UNIT 2 3/4 3-8 Amendment No. 90 ,

l INSERT A (i) At least once per 18 months, verify Turbine Stop Valve - Closure and Turbine Control Valve Fast Closure Valve Trip System Oil Pressure - Low Trip Functions are not bypassed when THERMAL POWER is > 25% of RATED THERMAL POWER. Specification 4.0.2 applies to this 18-month interval.

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INSTRUMENTATION

]

END-OF-CYCLE RECIRCULATION PUNI' TRIP SYSTEM INSTRUMENTATION j LIMITING CONDITION FOR OPERATION I

j 3.3.4.2 The end-of-cycle recirculation pump trip,(EOC-RPT) system instrumenta-

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

APPLICABILITY: OPERATIONAL CONDITION 1, when THERMAL POWER is greatt.r than or equal t .38('o f TED THERMAL POWER.

ACTION: 25'f?,

s a. With an end-of-cycle recirculation pump trip system instrumentation i channel trip setpoint less conservative than the value shown in the i Allowable Values column of Table 3.3.4.2-2, declare the channel l inoperable until the channel is restored to OPERAELE status hith the channel setpoint adjusted consistent with the Trip SetPoint value.

b. With the number of OPERABIJJ .: hannels one less than required by the

] . Minimum OPERABLE Channels per Trip System requirement for one or both trip systems, place the inoperable channel (s) in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

c. With the number of OPERABLE channels two er more less than required l by the Minimum OPERABLE Channels per Trip System requirement (s) for j one trip system ands

\_ 1. If the inoperable channels consist of one turbine control valve S. '

channel and one turbine stop valve channel, place both J. inoperable channels in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

. 2. If the inoperable channels include two turbine control valve

{ channels or two turbine stop valve channels, declare the trip

system inoperable.

l d. With one trip system inoperable, restore the inoperable trip system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , otherwise, either:

3 1 1. Increase the MINIMUM CRITICAL POWER (MCPR) Limiting Condition i for Operation (LCO) to the ROC-RPT inoperable value per Speci-

! fication 3.2.3 within the next I hour, or i

2. Reduce THERMAL POWER to less than )D( RATED THERMAL POWER within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . O 2.5%

e. With both trip systems inoperable, restore at least one trip system to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , otherwise, either ,

1. Increase the MINIMUM CRITICAL POWER (MCPR) Limiting Condition for Operation (LCO) to the EOC-RPT inoperable value per Speci-fication 3.2.3 within the next 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , or

2. Reduce THERMAL POWER to less than RATED THERMAL POWER within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

LA SALLE - UNIT 2. 3/4 3-39 Amendeent No. 113 W.

- l No eka.nges, prov>Aed 4hr con &st only.

INSTRUMENTATION SURVEILL9" REQUIREMENTS 4.3.4.2.1 Each end-of-cycle recirculation pump trip system instrumentation

. channel shall be demonstrated OPERA 8LE by the performance of the CHANNEL FUNCTIONAL TEST and CHAletEL CALIBRATION operations at the frequencies shown in Table 4.3.4.2.1-1.

1 4.3.4:2.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

4.3.4.2.3 The Ele-OF-CYCLE RECIRCULATION PtMP TRIP SYSTEM RESPONSF TIME of each trip function shown in Table 3.3.4.2-3 shall be demonstrated to be within its limit at least once per 18 sonths. Each test.shall include at least the .

logic of one type of channel input, turtrine control valve fast closure or

. tuttine stop valve closure, such that both types of channel inputs are tasted at least once per 36 months: The time allotted for breaker are suppression shall be verified by test at least once per'60 months.

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LA SALLE - UNIT 2 3/4 3-40

1

-EABLs 3.3.4.2-1

-[

t END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUNENTATION

!- [

MININUM TRIP FUNCTION OPERABLECHANNEgI ,

PER TRIP EYSTEM ;

1. Turbine stop Valve - Closure 2(b) i

2. Turbine Control Valve - Fast closure 2(b).

i not tal A trip system may placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance provided l that the other trip system is OPERABLE. p, I l (b) 1his function shall be automatically Liyessed ' -ikurbine first staae pressure is less than or equal g QTU peig, equivalent tj THERMAL POWER #ss than 30) of RATED ans.mnnL PGwER.

isyeas tw oregualto 252 LA SALLE - UNIT 2 3/4 3-41 Amendment No. 90

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

h i

g TA8tE 4.3.4.2.1 .

% .ifyi-OF-CYCLE RECIRCULATION PUNP TRIP SYSTEM SURVEILLANCE REOUIREMENTS

' t-7 CHANNEL FUNCTIONAL CHANNEL E TRIP FUNCTION (g') TEST CALIBRATION l

1. Turbine Stop Valve Closure R l Q

]

2. TurbineControlValve-Fast'ClosurEE Q R l i U .

A M t i i i

i m

9 i s ,

G-8 INSERT 8 i M .

S t

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

N INSERT B (a) At least once per 18 months, verify Turbine Stop Valve - Closure and Turbine Control Valve - Fast Closure Trip Functions are not bypassed when THERMAL POWER is > 25% of RATED THERMAL POWER. Specification 4.0.2 applies to this 18-month interval.

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INSTRUMENTATION BASES l

3/4.3.3 EMERGENCY CORE C00 LING SYSTEM ACTUATION INSTRUMENTATf0N (continued) l I specified surveillance intervals and surveillance and maintenance outage i times have been determined in accordance with NEDC-30936P-A, " Technical Specification Improvement Methodology (With Demonstration for BWR ECCS

]

- Parts 1 and 2. December 1988, and RE-025 Actuation Revision 1 Instrumentation

" Technical $ *lfication c Improvement Analysis for the Emergency l Core Cooling System Actu tion Instrumentation for LaSalle County Station, Units 1 and 2 April 1991. When a surveillances channel is placed entryininto an inoberable status ,

1 4 solely for performance of required LC and required l 4

ACTIONS may be delayed, provided the associated function maintains ECCS j initiation capaht11ty. j l 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION f 1 I The anticipated transient without scram L

system provides a means of limiting the conseq(ATWS) uences of therecirculation unlikely ' name trip i occurrence of a failure to scran during an anticioated transient. The I

response of the plant to this postulated event falls within the envelope of '

I study events in teneral Electric Company Topical Report NED0-10349 dated

! March 1971 and NEDD-24222, dated December,1979, and Appendix G of,the FSAR.

1

! The end-of-cycle recirculation pupp trip (E0C-RPT) systes is a cart of j the Reactor Protection System and is an essential safety supplement to the

reactor trip. The purpose of the E0C-RPT is to recover the loss of thermal i margin which occurs at the end-of-cycle. The physical phenomenon involved is

! that the void reactivity feedback due to a pressurization transient can add

positive reactivity to the reactor system at a faster rate than the control i rods add negative scram reactivity. Each EOC-RPT system trips both recircula-

! tion pumps, reducing coolant flow in order to reduce the void collapse in the

! core during two of the most Itaiting pressurization events. The two events

for which the EOC-RPT protective feature will function are closure of the j turbine stop valves and fast closure of the turbine control valves.

Analyses were performed to support continued operation with one or both ,

trip systems of the E0C-RPT inoperable. The analyses provide MIN!mM CRITICAL '

values which must be used if the EOC-RPT systes is j POWER inoperable.RATIO These (MCPR) MCPR limits are included in the COLR and ensure that adequate margin to the MCPR safety limit exists with the E0C-RPT function ! l inoperable. Application of these limits are discussed further in the bases !

for Specification 3.2.3. l A fast closure sensor from each of two turbine control valves provides input to the EOC-RPT systes a fast closure sensor from each of the other two turbine control valves provIdes input to the second EOC-RPT system.

Stailarly, a position switch for each of two turbine stop valves provides l input to one EOC-RPT system; a position switch from each of the other two stop

valves provides input to the other EOC-RPT system. For each EOC-RPT system, the sensor relar contacts are arranged to form a 2-out-of-2 logic for the fast closure of turbine control valves and a 2-out-of-2 logic for the turbine stop valves. The operation of either logic will actuate the EOC-RPT system and trip both recirculation pumps.

Each E0C-RPT system sa isadministrativelycontro15ed. be manually b ' bypasses and the automaticThemanuafassedbyuse Operating Bypass at less than.30rof RATED THERMAL POWER are annunciated in ,

the control room. .

25% ,

i i

LA SALLE - UNIT 2 8 3/4 3-3 Amendment No. 101 4

e tw A-yA.m.yr w 04i+ph443.44...M M4J--aR. Mm.-.4-USA AM E& .A d mA4.-eee-4h4Lpd*a mm.e=t-iFd#M Nda-4W Em e- a*ma Ew*&a.a4e_meacs.A+e3m.t .orme.aAs

_4h es-4-6 A u-MaF,end daa-J.aMe4 SAArA-4r e 4 ATTACHMENT C LASALLE COUNTY STATION EVALUATION OF SIGNIFICANT HAZARD CONSIDERATIONS FOR PROPOSED CHANGES TO l FACILITY OPERATING LICENSES NPF-11 AND NPF-18 APPENDIX A TECHNICAL SPECIFICATIONS i

)

ATTACHMENT C I g SIGNIFICANT HAZARDS CONSIDERATION I l

l Commonwealth Edison proposes to lower the current setpoint for the bypass of Turbine Control Valve (TCV) and Turbine Stop Valve (TSV) closure scram signals and End-of-Cycle Recirculation Pump Trip (EOC-RPT) signals. Reduction of the

, bypass setpoint (Pwn,,) results in simplified reload transient analyses and lower l

required core thermal operating limits. The analyses currently require more restrictive thermallimits between 25% and 30% of Rated Thermal Power, because the anticipatory TCV and TSV closure scrams do not occur and cannot be credited I in the analyses. Therefore, by lowering Pwy,, to 25% of Rated Thermal Power, the l complexity of reload analysis is reduced and operating margin is gained. This i results in increased operating flexibility.

4 The Pgy,, setpoint is based on first stage turbine pressure and is currently set at )

l 140 psig per Technical Specifications 3.3.1 and 3.3.4.2 (equating to 30% core l thermal power), it is proposed to be changed to delete reference to the turbine first stage pressure and to decrease Pwy,, to 25% of Rated Thermal Power. To assure the bypass is maintained, a requirement is added to periodically verify that the TCV and TSV Closure trip functions are not bypassed at greater than or equal to 25% of I Rated Thermal Power.

in addition, Technical Specification notes associated with Pwy,, applicability are l proposed to be corrected to accurately enforce the assumptions of the associated cycle specific pressurization analyses.

l l Commonwealth Edison 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 of occurrence or consequences of an accident previously evaluated:

! l l

The probability of an accident previously evaluated will not increase as a result of this change because the setpoint change does not alter any of the l initiators of an accident or cause them to occur more frequently. l C-1

e The consequences of an accident previously evaluated are not impacted.

LaSalle Units 1 and 2 each have approximately 30% bypass capability.

Therefore, a scram on TCV or TSV closure signals is not needed until 30% j core thermal power is reached, as adequate steam bypass capacity is available. A lower Poyp,,, remains conservative with respect to this criterion.

LaSalle utilizes power and flow dependent thermal limits. The power dependent portion of these thermal limits is dependent on the Pey,,,, setpoint.

These limits provide assurance that adequate fuel thermal-mechanical i margin is maintained through adherence to the thermal limits Technical Specification requirements.

Revised thermallimits have been determined based on the results of GE transient analyses. Adhering to these thermallimits ensures that the !

consequences of an accident or transient would not be increased from the consequences under the approved 30% setpoint. Adjustments to the thermal limits were determined through use of the NRC-approved ODYN reactor i dynamic model for the limiting Load Rejection Without Bypass and the l Feedwater Controller Failure events. j The deletion of the reference to turbine first stage pressure and rewording the Technical Specification Notes does not affect either accident initiators or plant j equipment, as they are administrative changes. !

Adding the periodic verification that the bypass channels are set correctly !

ensures that scrams or EOC-RPT will not be inadvertently bypassed when l Thermal Power is greater than or equal to 25% of Rated Thermal Power.

The statement that specification 4.0.2 applies to the 18 month interval is needed, since the notes are not standard surveillance requirements and the j interval is consistent with other similar instrumentation to which 4.0.2 l currently applies. !

Therefore, the proposed changes do not involve a significant increase in the '

probability of occurrence or consequences of an accident previously l evaluated. j

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

previously evaluated: j The setpoint change and proposed bypass verification notes ensure that the !

scrams for TSV closure and TCV fast closure, and EOC-RPT, will be enabled j l

above 25% of rated thermal power, rather than above 30% of rated thermal power. This change results in simplified reload transient analyses and does not impact any other equipment.

C-2 i i

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

i No other physical modifications are being proposed by this submittal. The only plant operational impact is that between 25% and 30% power, the plant will now scram upon a turbine trip, which is an analyzed transient.

The remaining changes to Technical Specification wording are administrative in nature and consistent with other Technical Specifications.

Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated, l

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

LaSalle Units 1 and 2 each have approximately 30% bypass capability. I Therefore, a scram on TCV or TSV closure signals is not needed until 30%

core thermal power is reached, as adequate steam bypass capacity is available. However, reduction of this setpoint to 25% power actually aids the plant transient response between 25% and 30% power, The new thermal limits reflect the revised setpoint and have been determined ;

based on revised limiting transient analyses that have included the new Peyp,,, !

value. If a transient were to occur, the revised operating limits ensure that adequate margin would be available to preclude violation of the Minimum Critical Power Ratio (MCPR) safety limit and the fuel thermal-mechanical limits.

, All other UFSAR events are either bounded by the analyses performed or are not impacted by the Poyp,,, change.

The wording changes to the Technical Specifications do not change the requirement for the bypass function and for maintaining the bypass function and thus do not affect the analyses discussed above.

The addition of the Notes periodically verifying the TCV and TSV Closure Trip Functions are not bypassed at greater than or equal to 25% of Rated Thermal Power ensures the trip functions will not be inadvertently bypassed when required to be Operable.

Therefore, the proposed changes do not involve a significant reduction in the margin of safety.

l C-3 L

l

.. .- .- - .. .... . . -~-. . . - . . - ..

h l

l 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 systern 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 10CFR50.92(c), the proposed change does not constitute a significant hazards consideration.

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

ATTACHMENT D ,

l LASALLE COUNTY STATION ENVIRONMENTAL ASSESSMENT STATEMENT FOR PROPOSED CHANGES TO l FACILITY OPERATING LICENSES NPF-11 AND NPF-18 APPENDIX A TECHNICAL SPECIFICATIONS 6.

i 6

h i

l ATTACHMENT D l I

ENVIRONMENTAL ASSESSMENT STATEMENT APPLICABILITY REVIEW l 1

I l

Comed has evaluated this proposed operating license amendment request against I the criteria for identification of licensing and regulatory actions requiring )

environmental assessment in accordance with 10 CFR 51.21. Comed has determined that the proposed license amendment request meets the criteria for a ;

categorical exclusion set forth in 10 CFR 51.22(c)(9) and as such, has determined I that no irreversible consequences exist in accordance with 10 CFR 50.92(b). This determination is based on the fact that this change is being proposed as an amendment to a license issued pursuant to 10 CFR 50 that changes a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or that change an inspection or a surveillance requirement, and the amendment meets the following specific criteria:

)

(i) The amendment involves no significant hazards consideration. l l

As demonstrated in Attachment C, this proposed amendment does not involve any significant hazards consideration.

(ii) There is no significant change in the types or significant increase in the l amounts of any effluent that may be released offsite.

As documented in Attachment A, there will be no change in the types or i significant increase in the amounts of any effluents released offsite.

(iii) There is no significant increase in individual or cumulative occupational radiation exposure.

I j The proposed changes will not result in changes in the operation or configuration of the facility. There will be no change in the level of controls or methodology used for processing of radioactive effluents or handling of solid radioactive waste, nor will the proposal result in any change in the normal radiation levels within the plant. Therefore, there will be no increase in individual or cumulative occupational radiation exposure resulting from this j change.

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ATTACHMENT E 1

GE ARTS IMPROVEMENT PROGRAM ANALYSIS FOR !

i LASALLE COUNTY NUCLEAR STATION, UNITS 1 AND 2 l REMOVAL OF DIRECT SCPAM BYPASSED LIMITS

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

4 i,

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l 2

2 j ATTACHMENT G l

NON-PROPRIETARY INFORMATION EXTRACTED FROM GENERAL ELECTRIC REPORT l

1

4 Attachment G Non-Proprietary information t 1 General Electric performed an evaluation to allow for changes to the ARTS basis for '

LaSalle Units 1 and 2. A change in the direct scram bypass power level (Pwy,,)

from 30% to 25% was analyzed. The change in power level to 25 % would

, effectively eliminate the below Pwy,, thermal limits because thermal limits art lot ;

l currently required to be known below 25% thermal power. In addition, the j evaluation analyzed the effect of both a revision to the ARTS basis assumed vessel '

dome pressure vs power to a new power dependent range specified by Comed and a revision to the LaSalle APRM flux scram setpoint from 122.4 to 124.2.

Results of the evaluation are presented in NEDC-31531P, Supplement 1, " ARTS Improvement Program Analysis for LaSaile County Nuclear Station, Units 1 and 2:

Removal of Direct Scram Bypassed Limits", dated September 1998. The tables and figures on the following pages contain the non-proprietary information that was able to be extracted from the GE report. They show assumed analysis conditions, plant response to the transients that were anayzed, and resultant thermal limits requirements. The remaining portion of NEDC-31531P, Supplement 1 is proprietary.

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. Table 1 Initial Conditions l

, 1 Parameter Angirsis g Value Thermal power MWt 830.75 a

Core flow, Mlb/hr . I13.93 Inlet enthalpy, Btu /lb 527.9 Steam flow, Mlb/hr 2.89 1

Feedwater Temperature, *F 236.1 (FWTR assumed) ;

. Dome pressure, psig 933 l

l 1'

i Table 2 Summary of Core Wide Transient Results Peak Equipt l

Initial Neutron - Peak Heat Out Power / Flux Flux of GE9B AQQ h (% NBR) (% initial) Service ER ICF/ Normal Feedwater Temp LRNBP 100/105 491 119 None 0.20

-LRNBP 100/105 595 124 RPT 0.24 FWCF 100/105 529 125 TBV 0.24 ICF/ Reduced

. Feedwater Temp FWCF 100/105 345 121 None 0.18

- FWCF 100/105 467 126 TBV 0.23 FWCF 25/105 59 154 None 0.59 FWCF 25/105 69 160 RPT 0.63 FWCF 25/105 80 164 TBV 0.70 x

1/ '

Table 3 OLMCPR and Kp Requirements l 4

OLMCPR OLMCPR Calculated Generic Limiting AOO E2w2t (Oct A) (Opt B)

KE K2 No EOOS -

LRNBP 100 1.33 1.29 1.0 1.0 FWCF .25. 1.76 1.74 1.35 1.55 RPTOOS LRNBP [00 1.37 1.33 1.0 1.0

' FWCF 25 1.80 1.78 1.34 1.55 TBVOOS FWCF 100 1.35 1.33 1.0 1.0 FWCF 25 1.88 1.86 1.40 1.55 Table 4 TOP / MOP and MAPFAC(p) Requirements Calculated Generic Limitine AOO E2*.gr .192 MQE MAPFAC(o) MAPFAC(o) l

-No EOOS LRNBP 100 24.9 25.2 1.0 1.0 FWCF 25 50.1 52.0 0.83 0.61 RPTOOS -

LRNBP 100 30.3 30.6- 1.0 1.0 FWCF 25 57.1 59.0 0.83 0.61 TBVOOS FWCF 100 28.7 30.0 1.0 1.0 FWCF 25 62.7 64.5 0.79 0.61

1 j i

Figure 1 Plant Response to FWCF 25% Power /105 % Flow 1 NEDIR001 FLUX AVE 1 VES IEL PREBS RISE (PSI)

I' C00 L SURFACE INLEi FL0ed HEAT FLUX 2 SAF :TT VALVE FLOW

... enn - tainrt nu. 3 REL :EF VALVE FLOW i STP LOS VALVE FLOW l

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Figure 2 Plant Response to FWCF 25% Power /105 % Flow without RPT I 1 REUTRW FLUX 1 VES IEL PRE 86 RIBE (PSI)

I 2 AVE SURFACE MEAT FLUX 2 5AF 'TT VALVE FLOW I 3 COR; INLET Fleti 3 REL :EF VALVE FLOW

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TIE tetteusel Ting tesce m es i LEV ',L(INCN-REF-BEP-BERT) 1 V01 ) REACTIVITV 2 VES lEL STEAMFLON 2 00P'LER REACTIVITY

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Figure 3 Plant Response to FWCF 25% Power /105 % Flow without TBV l l

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ses.e 1 NEUIRN FLUX 1 VES EL PRESS RISE (PS!!

SultFACE HEAT FLU 2 SAF :TY VALVE FLON I AVE COR , INLET FLN BREL :EF VALVE FLOW a ens : tan rt ana ise,, 1 SYP LS8 YALVE FLOW j

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l 1 LEV .L(INCN-REF-SEP-8KRT) i V01 ) REACTIVITV 8 VES EL STEA81FLN 8 D0PPLER REACTIVITY

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Figure 4 Power-Dependent M CPR Limit for Phypass at 30%

2.60 5,2.40 ;

- 2.4 0 ' ,/ > 5 0 % Flo w O PER ATING LIMIT MCPR(P) = Kp X OLM C PR(100) 30,2.30

.0- For P < 25% NO THERM AL LIMITS REQUIRED 50% Flow II offielet m onitoring is desire'd, the equations applicable

,25,2 for 25% power m ay be extrapoieted for 25% >P 2.00 -

30,2.00 For 25%'s P < 30%

O LM C PR(P) = K B Y P + 0.02(30% -P)

& K B Y P = 2.0 0 F o r s. 5 0 % Flo w K B Y P = 2.3 0 Fo r > 5 0% Flo w -

A .

O 2 For 30% s P < 45% Kp = 1.28 + 0.0134(4 5 % -P)

J O 1.60 - ,

For 45% s P < 80% Kp= 1.15 + 0.00 867(60% -P)

Ee '

' 30,1.48

n. - For 60% s P Kp=1.0 + 0.00375(10C %-P)

M 1.40 - -

45,1.28 1.20 -

60,1.15 1.00 s

25 35 45 55 65 75 85 95 PO W ER (% R ated)

)

t Fig u re 5 Power-Dependent MCPR Limit for Pbypass at 30% for EOOS Conditions 3.20 3.00 t

> 50% Flow 2.80 O P E R ATIN G LIMIT M C PR(P) = Kp X O LM C PR(100) ;

i For P < 25% NO TH ER M AL LIMITS R EQ UIR ED '

2.60 If official m onitoring is desired, the equations applicabfe for 25% power m ay be extrapolated for 25% >P 2.40 For 25% s P < 30% '

O LM C P R(P) = K B Y P + 0.04(30% -P) 25,2.20 K B Y P = 2.00 F o r s_ 5 0 % Flo w p 2.20 s 50% Flow K B Y P = 2.80 F o r > 5 0 % Flo w I

E .

h 2.00 -

30,2.00 For 30% s P < 45% Kp = 1.2 8 + 0.013 4 (4 5 % -P) 3 y _ For 45% s P < 60% K p= 1.15 + 0.00 8 67(6 0% -P) 3

~

j -

For 0% s P Kp= 1.0 + 0.003 75(100%-P)

D- 1.60 -

M 30,1.48 .

)

1.40 -

4 5 , 1 .2 fs 2 i

1.20 -

0,1.15 1.00 .

25 35 45 55 65 75 85 95 PO W E R (% R ated)

I

Figure 6 Power-Dependent M APLHGR Factor for Phypass at 30%

1.00 7 0.90 - -

t 0.80 - i 0.70 --

30,0.63

_ 0.60 -

0,0.55 For 25% > P NO THERM AL LIMITS REQUIRED

< 8 s50% Flow it tricial m nit rhg is desired, the equati ns applicable g

0.50 - 25,0.525 for 25% power may be extrapolated for 25%>P

< 30,0.47 3 8 r 25 % s P < 3 0 */.

25,0.4'4 0.40 - >50% Flow M APFACp=0.55+0.005(P-30%) For s50% Flow '

M APFACp=0.47+0.005(P-30%) For $50% Flow 0.30 For 30% s P M A PFA Cp= 1.0+0.005224(P-100%)

0.20 '

25 35 45 55 65 75 85 95 POWER (% Rated)

i Figure 7 Power-Dependent M CPR Limit for Pbypass at 25%

2.60 ,

2.4 0 8 >

O PER ATIN G LIMIT M C P R(P) = Kp X O LM C PR(100)

2. O For P < 25% NO THERM AL LIMITS REQUIRED i If official monitoring is desired, the equations applicable for 25% power m ay be extrapolated for 25% >P, provided {

that official m onitoring is only performed with the TCVITSV '

closure scram s and RPT enabled (Pbypass exceeded)

For 25% s P < 45% K p = 1.2 8 + 0.013 4(4 5 % -P)

E E

O.

1.80 For 45% s P < 60% Kp = 1.15 + 0.008 67(6 0% -P)

O lE For 60% s P K p = 1.0 + 0.00375(10 0 % -P) !

J

.g , 25,1.55 ;

C e !

CL t M 1.40 -

45,1.28 ;

L 1.20 60,1.15 ,

t 1.00 3 i 25 35 45 55 65 75 85 95 i PO W ER (% Rated) -

t I

Figure 8 Power-Dependent M APLHGR Factor for Pbypass at 25%

1.00 7

0.90 - -

0.80

0.70 --

_ 0.60 I 25,0.608 EL.

y For 25% > P NO THERM AL LIMITS REQUIRED 4 ff official monitoring is desired. the equations applicable g 0.50 - -

for 25% power may be extrapolated for 25%>P. provided q that official monitoring is only performed with the TCVITSV E (I closure scrams and RPT enabled (Pbypass exceeded) 0.40 --

For 25% s P M APFACp= 1.0+0.005224(P-100%)

0.30 - -

0.20 25 35 45 55 65 75 85 95 POWER (% Rated)

Figure 9 Flow-Dependent MCPR Limit 2.2 2

For Two Loop Operation, a 40% Wr MCPR(F) = The Maximum of EITHER 1.20 OR { -0.659 x (Wr/100) + 1.746 )

1.8 For Two Loop Operation. < 40% Wr i

b E

MCPR(F) = { -0.659 x (Wr/100) + 1.746 } x CL ( 1 + 0.0032 x (40-W ) ) ;

O 1.6 For Single Loop Operation, i MCPR(F) = 2.20 i

1.4 -- Wr = % Rated Core Flow l

1.2 1 ,

4 30 40 50 60 70 80 I 90 100 110 Core Flow (% Rateoj i

L t

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - -~ ~~ ' ~

I Figure 10 Flow-Dependent MAPLHGR Factor 1.1 1

0.9 "

i MAPLHGR(F) = MAPFAC(F) X MAPLHGRstd For Two Loop Operation 0.8 -

MAPFAC(F) = The Minimum of EITHER 1.0

{

O OR { 0.6784 x (Wr/100) + 0.4861 } ,

k O.7 -

For Single Loop Operation, Q MAPFAC(F) = 0.40 llE 0.6 __ Wr = % Rated Core Flow I

i 0.5 SLO 0.4 0.3 30 40 50 60 70 80 90 100 110 Core Flow (% Rated)

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - . - _ _ _ _ _ _ _ _ _ - - _ _ - - _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

ML20154M464

Text

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