Text

Proposed Tech Specs Incorporating Quarterly Surveillance Testing for Rt & ESF Actuation Sys Instrumentation,Per WCAP-10271
	ML20059D642
Person / Time
Site:	Beaver Valley
Issue date:	10/22/1993
From:	; DUQUESNE LIGHT CO.
To:	;
Shared Package
ML20059D628	List: ML20059D624; ML20059D642;
References
	NUDOCS 9311020344
	Download: ML20059D642 (116)
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ATTACHMENT A-1 Beaver Valley Power Station, Unit No. 1 Proposed Technical Specification Change No. 173 MARKED UP PAGES The following is a list of the affected pages:

Affected Pages: 3/4 3-2 3/4 3-4 3/4 3-5 3/4 3-6 3/4 3-7

3/4 3-11 3/4 3-12 3/4 3-13 3/4 3-15 3/4 3-18 3/4 3-20 3/4 3-21 '

3/4 3-29 3/4 3-29a 3/4 3-30 3/4 3-31 3/4 3-31a 3/4 3-31b B 3/4 3-1 i t

i a

I P ';

9311020344 931022

- PDR ADOCK 05000334 [jf'r

- P PDR 4

TABLE 3.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION -

g u

MINIMUM 7 TOTAL NO. CHANNELS CHANNELS APPLICABLE

FUNCTIONAL UNIT OF CHANNELS TO TRIP

OPERABLE MODES ACTION

1. Manual Reactor Trip 2 1 2 1, 2, 3h 4h, 12 l

and 50 l 2. Power Range, Neutron Flux l

l a. High Setpoint 4 2 3 1, 2 2

b. Low Setpoint 4 2 3 1(1), 2 2 6

3. Power Range, Neutron Flux 4 2 3 1, 2 2 High Positive Rate

4. Power Range, Neutron Flux 4 2 3 1, 2 2 High Negative Rate

5. Intermediate Range, Neutron 2 1 2 1 1), 2, 3 Flux and 56

6. Source Range, Neutron Flux (Below P-10)

a. Startup 2 1 2 2(2),

and5@g,4g, 4

b. Shutdown 2 0 1 3, 4, and 5 5

7. Overtemperature aT Three Lesp Opcr; tion 3 2 2 1, 2 7 7.; Leep Opcr; tion 2 l'^ 2 1, 2 ; l

8. Overpower AT Thre: Lccp Operaticr- 3 2 2 1, 2 7

"% Lccp Operation 3 l'^ 2 1, 2 l

9. Pressurizer Pressure-Low 3 2 2 1, 2 /

'^"""" "~

Replace 4 au$ (x) til A v i i< V AI.I.l. ( - tilll T I 3/4 3-2 A m e sul m e nit. fio ,

khD

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM $

TOTAL NO. CllANNELS CilANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

18. Turbine Trip (Above P-9)

A. Auto Stop Oil Pressure 3 2 2 1 7 B. Turbine Stop Valve 4 4 4 1 8 -

Closure

19. Safety Injection Input from 2 1 2 1, 2 1 ESF

20. Reactor Coolant Pump 1/ breaker 2 1/ breaker 1 11 Breaker Position Trip per (Above P-7) operating loop

21. Reactor Trip Breakers 2 1 2 , 40 2 1 2 4 Sh 39 l

22. Automatic Trip Logic 2 1 2 1 2 1 2 h 39 l

23. Reactor Trip System Interlocks A. Intermediate Range 2 1 1 2 3 Neutron Flux, P-6 B. Power Range 4 2 3 1 -12 Neutron Flux, P-8 C. Power Range 4 2 3 1 12 Neutron Flux, P-9 D. Power Range 4 2 3 1 12 Neutron Flux, P-10 E. Turbine Impulse 2 1 1 1 12 Chamber Pressure, P-13 A*Pl ace 4 w,W CV BEAVER VALLEY - UNIT 1 3/4 3-4 Amendment No.

Mopostp

DPR-is ,

TABLE 3.: * (C ntinued)

TA91E * : TAT!:?

(3)G with :he rea:ter trip systen creakers in the 21: sed prs;;. - l the : ntrol rod drive system capable of red withdrawal.

I -*

Th Charm: 1;:) :::: iated eith th0 pr tecti / functirne der- --

f f.;n th; cut f nervic 20;:ter CC lant LO:p chall he plar:d - ~

l th; trippcd nditier.

(1) Trip function may be manually bypassed in this Mode above P-10.

\ '

(2) Trip function may be manually bypassed in this Mode above P-6 ftshet inofet* sis lt Chenntl $

Nt e49d ACTION STATEMENTS g M M g y w,$* g le,,,y a ACTION 1 -

With the numbe OPERABLE Channels e less than the Minimum Channels ERABLE requirement, be in at least j HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up hours for surveillance testing per specification 4.3.1.1,1,provided the other channel is OPERABLE.

9 ACTION 2 -

th the number of OPERABLE channels one less than t .

To 1 Number of Channels and with the THERMAL P ER leve :

s_ .

MEE/ '

a. Le than or equal to 5% of RATED THERMA POWER, !

plac the inoperable channel in th tripped conditi n within 1 hour and r store the inoperab channel to OPERABLE sta s within 24 l hours aft increasing THERMAL POW above 5% of i RATED THERP POWER; otherwise, reduce thermal i power to les than 5% RATED TH L POWER within l the following 6 urs.

i

b. Above 5% of RAT THERMAL OWER, operation may j continue provided a of th following conditions I are satisfied:

1. The inoperable c n 1 is placed in the tripped condition ithi 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2. The Minimum Ch nels OPE BLE requirement .s met; however, one additio 1 channel may ce bypassed fo up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months r surveillance testing per Specification 4.3.1. .

3. Either, ERMAL POWER is restric d to < 5, of RA THERMAL and the Pow Range, Neutro Flux Trip setpoint is redu d t: _

85% f RATED THERMAL POWER within 4 . ura:

or, the QUADRANT POWER TILT RATIO .3 m itored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months : -

ecification 4.2.4.c.

ACTION 3 -

With the number of channels OPERABLE one less t- -

required by the Minimum Channels OPERABLE require- --

and with the THERMAL POWER level:

BEAVER VALLEY - UNIT 1 3/4 3-5 Amendment No.

fA0N$&

In' sert 1 -

ACTION 2 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1, and '

c. Either, THERMAL POWER is restricted to less than or equal to 75 percent of RATED THERMAL POWER and the Power Range Neutron Flux setpoint is reduced to less than or equal to 85 percent of RATED THERMAL POWER within 4 hours; or, the QUADRANT !

POWER TILT RATIO -is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification'4.2.4.c.

Insert 2 ACTION 7 - With the number. of OPERABLE channels (4) one less than the Total Number of Channels, .STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and i

b. The Minimum Channels OPERABLE requirement is met; i however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance' testing of other channels per Specification 4.3.1.1.1.

I l

l l

l

,, ,DPR-66 TABLE 3.3-1 (Continued) l

a. Below P-6, restore the inoperable channel-to OPERABLE status prior to increasing THERMAL POWER above the P-6 setpoint. jerconf

b. Above P-6 but below SS)of RATED THERMAL POWER, restore i the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above of POWER. PC6nf EtMl RATED THERMAL l

c. Above of RATED THERMAL POWER, POWER OPERATION may l continue. :

ACTION 4 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a. Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 setpoint. !

b. Above P-6, operation may continue.

ACTION 5 - With the number of channels OPERABLE one less than i required by the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN requirements of Specification 3.1.1.1 or Specification 3.1.1.2, ,as applicable within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , j and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter. j ACTION 6 - Not Applicable ggg gg gg7 y D ACTION 7 - 'ith the number of CPERABLE channels b ne less than '

I the Total Number of Channels and with the THERMAL l POWER level ,

I

a. Less than or equal to 5% of RATED THERMAL POWER, place .

the inoperable channel in the tripped condition within l 1 hour; restore the inoperable channel to operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after increasing THERMAL POWER-above 5% of RATED THERMAL POWER; otherwise reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. Above 5% of RATED THERMAL PCWER, place the inoperable channel in the tripped condition within i hour; operation may continue until performance of the nex required CHANNEL FUNCTIONAL TEST.

ACTION 8 - With the number of OPERABLE channels one less than the Total Number of Channels and with the THERMAL POWER level above P-7, place the i perable channel in the tripped condition within houd; operation may I continue until performance of the next required CHANNEL FUNCTIONAL TEST. g h)hAn leg, OPERABLE hot leg channel consists of: 1) three RTDs per hot or 2) two RTDs per hot leg with the failed RTD disconnected l

and the required bias applied.

BEAVER VALLEY - UNIT 1 4 3-6 Amendment No.

Of6SEb

DPR-66 TABLE 3.3-1 (Continued)

ACTION 9 -

W ay/Mie.

. a channel associated with an operating

'-_ y inopera , "estore the inoperable cha L-tr OPERABLE s or STANDBY with the

~

status within next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; how * , nnel associated with an operati may be bypassed to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for elllance testing per Specification 4.3. . .

ACTION 10 - Not applicable.

ACTION 11 - With less than the Minimum Number of Channels OPERABLE, operation may continue provided the inoperable cpannel is placed in the tripped condition within ( } hou . I ACTION 12 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 39 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour.

t nef.

ACTION 40 - a. With one of the / diverse trip featuresa (undervoltage or shuyt trip attachment) of reactor trip breake inoperable, restore the diverse trip feature to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in HOT STANDBY within 6 hours. Neither breaker 1 shall be bypassed while one of the diverse trip features is inoperable except for the time required for performing maintenance to restore the breaker to OPERABLE status.

b. With one reactor trip breaker inoperable as a result of something other than an inoperable diverse trip feature; be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1/jprovided the l other channel is OPERABLE.

BEAVER VALLEY - UNIT 1 3/4 3-7 Amendment No.

(next page is 3/4 3-9)

McPosEb

TABLE 4.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS g m

Channel Modes in Which y Channel Channel Functional Surveillance m Functional Unit Check Calibration Test

Reauired

1. Manual Reactor Trip N.A. N.A. S/U(1), N.A.

R(10)

2. Power Range, Neutron Flux

a. High Setpoint S D(2),M(3) -M-- G 1, 2 l and Q(6)

b. Low Setpoint S N.A. S/U(1) 2

3. Power Range, Neutron Flux, N.A. R -M-- Q 1, 2 High Positive Rate

4. Power Range, Neutron Flux, N.A. R -M-Q 1, 2 High Negative Rate

5. Intermediate Range, Neutron S N.A. S/U(1)@>- 1 2 Flux -T '7) Sh , 3h 4h

6. Source Range, Neutron Flux N.A. N.A. S/U(1), 2, 3, 4 and S (Below P-10) -Mte)-Q(8)

7. Overtemperature AT S R + GL 1, 2

8. Overpower AT S R -M- Q 1, 2

9. Pressurizer Pressure-Low S R -tt 'Q 1, 2

10. Pressurizer Pressure-High S R -M- Gt ' 1, 2

11. Pressurizer Water Level-High S R -M- Q 1, 2

12. Loss of Flow - Single Loop S R -M- Q 1

13. Loss of Flow - Two Loops S R hQ 1

14. Steam / Generator Water S R -M- Q 1, 2 i 1.e ve 1 - 1.ow - Low

g BEAVER VALLEY - UNIT 1 ,314 3-11 Amendment tio .

tW0 POSED

TABLE 4.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENT &TJ9N SURVEILLANCE REOUIREMENTS

~

-g m

Channel Modes in Which 7 Channel Channel Functional Surveillance m Functional Unit Check Calibration Test Reauired

15. Steam Feedwater Flow Mismatch S R -M-f( 1, 2 and Low Steam Generator Water [

Level

16. Undervoltage-Reactor Coolant N.A. R N 1 Pumps

17. Underfrequency-Reactor Coolant N.A. R H 1 Pumps

18. Turbine Trip

a. Auto Stop Oil Pressure N.A. N.A. S/U(1) 1, 2 ,

b. Turbine Stop Valve N.A. N.A. S/U(1) 1, 2 Closure

19. Safety Injection Input from N.A. N.A. R 1, 2 ESP

20. Reactor Coolant Pump Breaker N.A N.A. R N.A Position Trip

21. Reactor Trip Breaker N.A. N.A. N(5, 11) 1 Sd) 2, 3I)4dh and S/U(1)

22. Automatic Trip Logic N.A. N.A. N(5) b 1

,2 3I) 452

23. Reactor Trip System Interlocks A. P-6 N.A. N.A. M(0) - R 1, 2 B. P-8 C. P-9 N.A.

N.A.

N.A. M(0) /t 1 D. P-10 N.A.

N.A.

M(9) ( 1 M(0) g 1 E. P-13 N.A. R M(S) 4 1

24. Reactor Trip Bypass Breakers N.A. N.A. M(12),

Replace + 4 Qv) 1 A , 23k) 4$k, l

BEAVER VALLEY - UNIT 1 "j{;

)]4 3-12 FNOf0TfD Amendment No.

,, ,DPR-66 TABLE 4.3-1 (Continued)

NOTATION (N)() -

With the reactor trip system breakers closed and the l [

control rod drive system capable of rod withdrawal. >

3tl ,

(1) -

If not performed in previous 9-days. l i jtfCtnt (2) -

Heat balance only, above 1 @ of RATED THERMAL POWER. l (3) -

Compare incore to excore axial imbalance above 150 of RAT D THERMAL POWER. Recalibrate if absolute difference 2 3 percent. _

(4) -

(Not Used)

{etefte jg % o (5) -

Each train tested every other month.

(6) -

Neutron detectors may be excluded from CHANNEL CALIBRATION.

(7) -

Below P-10.

(8) -

Below P-6.

-(O R;quir:d only wh;n below Interi;;k Trip Cetpoint. 6Yetopgeg)l (10) -

The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip circuits for the Manual Reactor Trip Function. The test shall also verify the OPERABILITY of the Bypass Breaker trip circuit (s).

(11) -

The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

(12) -

Local manual shunt trip prior to placing breaker in service.

(13) -

Automatic undervoltage trip.

j BEAVER VALLEY - UNIT 1 3/4 3-13 Amendment No.

PROAosEb

TABLE 3.4-3 .

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION _a

*v A3 i

MINIMUM

TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation 2 1 2 1, 2, 3, 4 18

b. Automatic Actuation 2 1 2 1, 2, 3, 4 13, 36 Logic

c. Containment 3 2 2 1, 2, 3 14 Pressure-High

d. Pressurizer Pressure-Low 3 2 2 1, 2, h 14 l

e. Low Steamline Pressure

-(L;;p step :1fre epen)

Three Leepr Operating 3/ loop 2/ loop any loop' 2/ loop any loop 1, 2, h 14

?.:: n:p: Cper: ting 2/12 p 2/12:; 2/:ny 1, 2, 2 ." :s

ny rperating ep;r: ting 1; loop Replact # a A G) i s t A V I .1< V A l.i.l.Y - UNIT I 3 4 3-15 '

Amendment Ib > .

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 6 u

u I

MINIMUM

TOTAL NO.

CHANNELS CHANNELS APPLICABLE ZyliCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

4. STEAM LINE ISOLATION

a. Manual 2/ steam line 1/ steam 2/ operating 1, 2, 3 18 line steam line

b. Automatic Actuation 2 1 2 1, 2, 3 13 Logic

c. Containment Pressure 3 2 3 1, 2, 3 14 Intermediate-High-High

d. Low Steamline Pressure

--(1,0cp Step ValJ rpen)

"t.r;: 1.cep Operating 3/ loop 2/ loop 2/ loop any 1, 2, 14 any loop loop "to I,capc Oper-at4ng 3/ loop 2/100p 2/ ny 1, 2, 3f ;S

- ;n"/ n;;r; ting ep: rating leep 1;;;

e. High Steam Pressure Rate 3/ loop 2/ loop any loop 2/ operating loop h ;; fi/

Replace # waA (o

$tplact. & JtN(A)

ULAVI.it VALI.LY - UNIT 1 3 4 3-18 Amendment No.

rk0AOfLth

- e h DPR-66 TABLE 3.3-3 (Continued) -!

TABLE NOTATION (h( Trip function may be bypassed in this MODE below P-11. I (A)(3 Trip function automatically bypassed above F-11, and is' bypassed. [

below P-11 when Safety Injection on low steam pressure is not manually bypassed. !

-fff The ch:. n:1 (c) :::: icted eith th: protective function: deriv d ,

frc th eut Of cervie: Re ter 00:1:nt LO p ch:ll b: pl:: d in ;

m_2___2 __2-

m. .. .u _ ...rr-- ---.. >

ACTION STATEMENTS af Im'/~ '

ACTION 13 -

1s one less than the g With T;t:1 theNumber numberof of Channels, OPERABLEbeChang in H OT STANDBY within-es* /2.

hours and in COLD SHUTDOWN within the following 30 -

hours; however, one channel may be bypassed for up to 4 it;; hours for surveillance testing per Specification :

4.3.2.1.1, provided the other channel is operable. I k

ACTION 14 -

th the number of OPERABLE Channels one less than t Tot umber of Channels: *

)UUbbkI 5 a. Below or P-12; place the ino le channel in the tr d condition'with hour; restore the inoperable nnel to O LE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after exce n -11 or P-12; otherwise be in at least HOT within the following six hours.

b. Above P-11 ,d P-12, place the inoper channel' in the pped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; op tion may continue until performance of the n ired CHANNEL FUNCTIONAL TEST.

ACTION 15 -

c nnel associated with an operatin inoperab , tore the inoperable chann ERABLE status within 2 ho be in H WN within the ,

following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; h , channel associated with an operat oop may be bypa up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months surveillance testing per Speci 1

. .1.1. '

ACTION 16 -

the number of OPERABLE Channels one less than Total f Channels: ,

INJEAT V4 a. Below P-11 or P- , noperable channel bypass in the co on; e the inoperable '

channel to LE status within s after excee P-11 or P-12; otherwise be in at SHUTDOWN within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

l

' I BEAVER VALLEY - UNIT 1 3 4 3-20 Amendment No.

NO I _ . _ . _ _ ,_ _ . _ __ .. _

Insert 3 ACTION 14 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER-OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable . channel is placed in theftripped.

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

'l

b. The minimum channels OPERABLE requirement is met; i however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance. testing of other channels per Specification 4.3.2.1.1. :

1 l

Insert 4 ACTION 16 -

With the number of OPERABLE' channels one less.than the l Total Number of Channels, operation may proceed- l provided the inoperable channel is. placed- in' the bypassed condition -and .the Minimum Channels OPERABLE requirement is met. One additional channel may be ]

bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .for' surveillance testing ;

per Specification 4.3.2.1.1. j Insert A ACTION 34 -

With the number of OPERABLE' channels one less than the Total Number of Channels, -STARTUP and/or POWER' OPERATION- may proceed provided the following conditions are satisfied:-

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed i for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of j other channels per' Specification'4.3.2.1.1.

I

)

., l

l DPR-66 TABLE 3.3-3 (Continued)

ACTION STATEMENTS

.CT! =' 1: -

L. Abnve P-11 or P-12, demonstrate that the Mi-4' (C;ntinued; Channels veERA:Er recuirement is - * . In 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; operation may continue -

i -..

^

inoperable channel bypassed a . c annel may be bypassed tot up tc L or testing per Specification 4.3.2.1.

ACTION 17 -

ht opplicah=.

nica 2: -- " *ha Minimum Channels OPERABLE. npa"'ti n i..ay-continue provided tha cantninueuu puty a and e-x hauct "=1"a=

_ ave ;1aLainec closed.

ACTION 18 -

With the number of OPERABLE Channels one less than the

,_.,,m_, ,,.. ' - ' ^ --- '-

restore the inoperable channel to l status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT g.p g g n8gg g OPERABLE STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and COLD 4 SHUTDOWN within I the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . Lln 1 ACTION 33 -

With the number of OPERABLE Channels one less than the Total Number of Channels, the Emergency Diesel Generator associated with the 4kv Bus shall be declared inoperable and the ACTION Statements for Specification 3.8.1.1 or Specification 3.8.1.2, as appropriate, shall apply.

ACTION 34 -

W[th he number of OPERABLE Channels one less than th Total Number of Channels, STARTUP and/or POWER OPERATION l

.j may proceed until the performance of the next required f(f gg gdg

.1'rsetp g ~~il Channel Functional i

Testprovidedtheinoperablechannel1}y hourf i

(placed in the tripped condition within Q g _ _

ACTION 36 -

The. block of the automatic actuation logic introduced by a i reset of safety injection shall be removed by resetting

{

(closure) o f' the reactor trip breakers within one hour of l an inadvertent initiation of safety injection providing i

that all trip input signals have reset due to stable plant l

conditions. Otherwise, the requirements of cti n-I l statement 13 shall have been met. [C77 8 ACTION 37 t abelk ahle.

W e n e ar of OPERABLE channels one less than t Tota er of channels, STARTUP and/or POWER O . TICN may procee rovided the following co ions are satisfied:

a. The inoperable channe placed in a tripped condition within one .

b. The Minimum C els OPERABLE requi ts is met; however, inoperable channel may be bypas- or up to 2 urs for surveillance testing of other chan. '-

Specification 4.3.2.1.1.

ACTION 38 -

With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window (s) (bistable status lights :r computer checks) that the interlock is in its requ; red state for the existing plant condition, or app.y Specification 3.0.3.

BEAVER VALLEY - UNIT 1 3 4 3-21 Amendment No.

IbIfD

6

o TABLE 4.3-2 E as ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL

MODES IN WHICil t CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

1. SAFETY INJECTION AND FEEDWATER ISOLATION l a. Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4

b. Automatic Actuation Logic N.A. N.A. M(2) 1, 2, 3, 4

c. Containment Pressure-High S R' -M- Q 1, 2, 3

d. Pressurizer Pressure--Low S R PQ 1, 2, 3

e. Steam Line Pressure--Low S R -M- Q 1, 2, 3 BEAVER VALLEY - UNIT 1 3/4 3-29

Amendment No.

At0POSEb

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION .

SURVEILLANCE REOUIREMENTS ?,

7 CHANNEL MODES IN WilICli CilANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 1.1. SAFETY INJECTION-TRANSFER FROM INJECTION TO THE RECIRCULATION MODE

a. Manual Initiation N.A. N.A. M (1) 1, 2, 3, 4

b. Automatic Actuation N.A. N.A. M (2) 1, 2, 3 Logic Coincident with Safety Injection Signal

c. Refueling Water Storage S R M 1, 2, 3 Tank Level-Low

d. Refueling Water Storage S R M 1, 2, 3 Tank Level - Auto QS Flow Reduction

2. CONTAINMENT SPRAY

a. Manual Initiation N.A. N.A. M (1) 1, 2, 3, 4

b. Automatic Actuation N.A. N.A. M (2) 1, 2, 3, 4 Logic

c. Contain Pressure-High-High S R +Q 1, 2, 3 l.

HLAVLH V A I,1, L Y - UNIT 1 3/4 3-29a Amendment No.

!RoPOSED

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS '@,

7 CilANNEL MODES IN WiiICli CliANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

3. CONTAINMENT ISOLATION

a. Phase "A" Isolution

1) Manual N.A. N.A. M(1) 1, 2, 3, 4

2) From Safety Injection N.A. N.A. M(2) 1, 2, 3, 4 Automatic Actuation Logic

b. Phase "B" Isolation

1) Manual N.A. N.A. M(1) 1, 2, 3, 4

2) Automatic Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic

3) Containment Pressure-- S R -M- Q '1, 2, 3 l liigh-liigh HEAVER VALLEY - UNIT 1 3/4 3-30 PROP 0TEb

__ - _ __-___ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ ~ _ - . ... . . __ _ __ ._ . - _ - - -- _ _-_ ____ _ ___-

1 TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS $

7 m

m CHANNEL MODES IN WHICII CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

4. STEAM LINE ISOLATION ,

a. Manual N/A N/A M(1) 1, 2, 3

b. Automatic Actuation Logic N/A N/A M(2) 1, 2, 3

c. Containment Pressure-- S' R -M-Q 1, 2, 3 Intermediate-High-High

d. Steamline Pressure--Low S R -M-Q 1, 2, 3

e. Steamline Pressure Rate-High S R -M-@ 1, 2, 3

5. TURBINE TRIP AND FEEDWATER ISOLATION

a. Steam Generator Water S R -M-Q 1, 2, 3 Level--High-High

6. LOSS OF POWER

a. 4.16kv Emergency Bus _

N/A R M 1, 2, 3, 4 Undervoltage (Loss of Voltage)

Trip Feed & Start Diesel

b. 4.16kv and 480v Emergency _ N/A~ R M 1, 2, 3, 4 Bus Undervoltage (Degraded Voltage)

BEAVER VALLEY -_ UNIT 1 3/4 3-31 Amendment No.

L PROPOSED

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION -y SURVEILLANCE REOUIREMENTS m 7

m m

CHANNEL MODES IN WilICli CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

7. AUXILIARY FEEDWATER

a. Steam Generator Water 4t-Q Level-Low-Low S R 1, 2, 3 l

b. Undervoltage - RCP S. R M 1, 2

c. S.I. See 1 above (all SI surveillance requirements)

d. Emergency Bus N/A R R 1, 2, 3 Undervoltage

e. Trip of Main Feedwater Pumps N/A }{/A R 1, 2, 3 BEAVER VALLEY - UNIT 1 ,3/4 3-31a Amendment No.-

fRoteds9

- - - , . - - ..--.---e,-,- .. _m...m.-_.-.<-..-.,wo. #- .. . , - - . . v- ., --..-w-- - - , ,

l TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION g SURVEILLANCE REOUIREMENTS 'o 7

?.

CHANNEL MODES Ill WilICli CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK .

CALIBRATION TEST REOUIRED

8. ESF INTERLOCKS

a. P-4 N/A N/A R 1, 2, 3

b. P-11 N/A R -M-- Q 1, 2, 3

c. P-12 N/A R -M- Q 1, 2, 3 Mod h p M ,s/j a t,sp.,

Ytb 4.

bl AVI 1, '

. Al I t i - lif41T I gja 3 3 1., Amendment 110.

f0NS$

.. peR-66 3/4.3 INSTRUMENTATION BASES 1

)

3/4.3.1 AND 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATCPES 'EST l INSTRUMENTATION ;

i The OPERABILITY of the protective and ESF instrumentation systers 1 and interlocks ensure that 1) the associated ESF action and/or l reactor trip will be initiated when the parameter monitored by each !

channel or combination thereof exceeds its setpoint, 2) they, l specified coincidence logic is maintaincd, 3) sufficient redunden j l channel to be cut of service for testic e

-i; maint:ined to

=cr maintenance, and permit)t) 3 sufficient system functional capability 'is available for protective and ESF purposes from diverse parameters.

The OPERABILITY of these systems is required to provide the overall reliability, redundancy and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systams is consistent with the assumptions used in the accident analyses.

The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards. The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability. R y gggg7. g l The surveillance requirements for the Man,ual Trip Function, Reactor

. Trip Breakers and Reactor Trip Bypass Breakers are provided to reduce the possibility of an Anticipated Transient Without Scram (ATWS) event by ensuring OPERABILITY of the diverse trip features

(

Reference:

Generic Letter 85-09).

The measurement of response time at the specified frequencies provides assurance that the protective and ESF action function associated with each channel is completed within the time limit i assumed in the accident analyses. No credit was taken in the analyses for those channels, with response times indicated as nct ,

applicable. pg )

ESF response timq$ specified in Table 3.3-5 which include l sequential operation of the ST and VCT valves (NOTES # and ##) are based on values assumed on the Non-LOCA safety analyses. These l analyses take credit for injection of borated water.. Initia; borated water is supplied by the BIT, however, injection of borated water from the RWST is assumed not to occur until the VCT charg:.g pump suction valves are closed following opening of the E'.; 3 I i I

charging pump suction BEAVER VALLEY - UNIT 1 B 3/4 3-1 Amendment No.

9R090S%

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

Insert i and sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance consistent with maintaining an. appropriate level of reliability of the Reactor Protection and Engineered Safety Features instrumentation , and Insert 6 Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP - 10271, ;

" Evaluation of Surveillance Frequencies and-Out'of Service Times for '

the Reactor Protection Instrumentation System," and supplements to that report as approved by the NRC and documented in the SER (letter ,

to J. J. Sheppard from Cecil.O. Thomas, dated February 21, 1985). l Jumpers and lifted leads are not an acceptable nethod for placing equipment in bypass as documented in the . NRC safety evaluation ,

report for this WCAP. {

i i

I I

.J

i ATTACHMENT A-2 i Beaver Valley Power Station, Unit No. 2

Proposed Technical Specification Change No. 35 MARKED UP PAGES The following is a list of the affected pages

Affected Pages: 3/4 3-2 3/4 3-4 3/4 3-5 3/4 3-6 3

3/4 3-7 3/4 3-10 3/4 3-11 3/4 3-12 3/4 3-13 3/4 3-16 3/4 3-18 ,

3/4 3-19 '

3/4 3-21 '

3/4 3-22 '

3/4 3-33 3/4 3-34 3/4 3-35 ,

3/4 3-36 3/4 3-37 B 3/4 3-1 i

h

TABLE 3.3-1 E _

$ REACTOR TRIP SYSTEM INSTRUMENTATION z 9 %

C MINIMUM b p TOTAL NO. CHANNELS CHANNELS APPLICABLE Q FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES AC110N

1. Manual Reactor Trip 2 1 2 2 , 40, 12 l

" 2. Power Range, Neutron Flux

a. High Setpoint 4 2 3 Iggj 2

b. Low Setpoint 4 2 3 1 ,2 2

3. Power Range, Neutron Flux 4 2 3 1, 2 2 High Positive Rate g 4. Power Range, Neutron Flux, 4 2 3 1, 2 2 High Negative Rate

5. Intermediate Range, Neutron 2 1 2 III,2, , 3 C Flux and tf

6. Source Range, Neutron Flux (Below P-10)

a. Startup 2 1 2 2(2) J , p

, 4 l

and T)

b. Shutdown 2 1 2 3, 4 and S 5

7. Overtemperature AT Three Loop Operation 3 2 2 1, 2 7

8. Overpower AT Three Loop Operation 3 2 2 1, 2 7

9. Pressurizer Pressure-Low 3 2 2 1, 2 7 (Above P-7)

10. Pressurizer Pressure-High 3 2 2 1, 2 7 Replace w wo A (1)

. TABLE 3.3-1 (Continued) 9 =; !

M REACTOR TRIP SYSTEM INSTRUMENTATION @

j i

< 4

MINIMUM E TOTAL NO. CHANNELS CHANNELS APPLICABLE y FUNCTIONAL UNIT OF. CHANNELS TO TRIP OPERABLE MODES ACTION E 19. Safety Injection Input -

. 't from ESF 2 1 2 1, 2 1 na

20. Reactor Coolant Pump Breaker Position Trip (Above P-7) 1/ breaker 2 1/ breaker 1 11 per operating loop T 21. Reactor Trip Breakers 2 1 2 1 2 40 hw 2 1 2 M 4k and b 39 l

22. Automatic Trip Logic 2 1 2 2 1 4

rn 2 1 2 8, and O 39 l

23. Reactor Trip System i Interlocks-

a. Intermediate Range 2 1 2 2 44 Neutron Flux, P-6

b. Power Range 4 2 3 1 44 Neutron Flux, P-8

g. c. Power Range .

4 2 3 1 44 g Neutron Flux, P-9

d. Power Range 4 2 3 1, 2 44

<+ Neutron Flux, P-10

E

e. Turbine Impulse .

2 1 2 1 44 Chamber Pressure, P-13 Repace + wA 6)

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

NPT-73 k

MBLE 3.3-1 fCont i Lec' TABLE NOTATICN (3) th the reactor trip system breakers in the closed position and tne control l rod drive system capable of rod withdrawal.

j (1) Trip function may be manually bypassed in this MODE above P-10.

(2) Trip function may be manually bypassed in this MODE above P-6.

.m f g4 ACTIONSTATEMENTSg46tfgs, a w?Aiepenue 6 dowNMis er i

ACTION 1 - l With the number of OPERABLE ch nels one less than the Minimum Channels OPERABLE. requirement, e in at least HOT STANDBY withi_n hours; however, one channel may be bypassed for up to hours for surveillance testing per Specification 4.3.1.1.l;provided the i other channel is OPERABLE.

l l ACTION 2 - th the number of OPERABLE channels one less than the Tot l N er of Channels and with the THERMAL POWER level: '

.INISAT / -+ a. Le than or equal to 5% of RATED THERMAL POWER place the i inop ble channel in the tripped condition w' in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

and res re the inoperable channel to OPE status within i , 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ter increasing THERMAL POWER a e 5% of RATED l

THERMAL POW otherwise reduce thermal ower to less than 5% RATED THE POWER within the foil ing 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. Above 5% of RATED RMAL POWER, o ration may continue provided all of the f owiig co itions are satisfied:

1. The inoperable channe placed in the tripped condi-tion within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2. The Minism Chann s OPERA 8L equirement is met; how-

" ever, the inope le channel na be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for s veillance testing other channels per Specificati 4. 3.1.1.

3. Either, ERMAL POWER is restricted to < of RATED THE and the Power Range, Neutron Flux t setpoint is uced to <85% of RATED THERMAL POWER wit 4 urs; or, t5e QUADRANT POWER TILT RATIO is no tored least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification 4.2.4.

ACTION 3 - With the number of channels OPERA 8LE one less than required by the Minimum Channels OPERA 8LE requirement and with the THERMAL POWER level:

a. Below P-6, restore the inoperable channel to OPERA 8LE status prior to increasing THERMAL POWER above the P-6 setpoint. ;

BEAVER VALLEY - UNIT 2 g4yg

Insert 1 ACTION 2 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1, and

c. Either, THERMAL POWER is restricted to less than or equal to 75 percent of RATED THERMAL POWER and the Power Range Neutron Flux setpoint is reduced to less than or equal to 85 percent of RATED THERMAL POWER within 4 hours; or, the QUADRANT POWER TILT RATIO is monitored at least once per '

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification 4.2.4.c.

l Insert 2 ACTION 7 - With the number of OPERABLE channelsI4) one less than the Total Number of Channels, STARTUP and/or ;

POWER OPERATION may proceed provided the following conditions are satisfied: ,

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1. I i

l l

!I

NPF-73 TABLE 3.3-1 (Continued) '

5. 2 0cve ;-6 Sut elcw 5hpt+ Lent of RATED THERMAL POWER, restore e l incceracle cnannel to PERABLE status prior to increasi..;

HERMAL DOWER aceve ,

of RATED THERMAL PCWER. I yPertent c.

Above 5$1of RATED THERMAL POWER, POWER OPERATION may continue. l ACTION 4 -

With the number of channels OPERABLE one less than required my the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

g a.

BelowP-6,restoretheinoperablechannf1toOPERABLEstatus prior to increasing THERMAL POWER above P-6 setpoint and l suspend positive reactivity operations.

j

b. Above P-6, operation may continue.

ACTION 5 -

With the number of OPERABLE channels one less than the Minimum Channels OPERA 8LE requirement, restore the inoperable channel to OPERA 8LE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the Reactor Trip System breakers, suspend all operations involving positive reactivity changes and verify Valve 2CHS-91 is closed and secured in position within the next hour. i ACTION 6 - This Action is not used. l g

ACTION 7 -

N th the number of OPERABLE channel ne less than the To of Channels and with the THERMAL POWER level:

a. }

Less tha r equal to 5% of RATED THERMA inoperable c R, place the el in the tripped co on within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; i

[MYA.7 -

restore the inope 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after increa le channel t TH erable status within L POWER above 5% of RATED THERMAL POWER; otherwise

.e THERMAL POWER to less than SX of AATED THERMAL R with he following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. Above 55 of D THERMAL POWER, place inoperable channel the tripped condition within 1 ho may operation tinue until performance of the next requ L FUNCTIONAL TEST.

ACTION 8 -

Wfth the number of OPERA 8LE channels one less than the Total Number of Channels and with the THERMAL POWER level above P-9, 5 lace the inoperable channel in the tripped condition within houd, operation may continue until perfomance of the next required CHANNEL FUNCTIONAL TEST. l ACTION 9 -

This ACTION is not used Mn OPERA 8LE hot leg channel consists of:

1) three RTD's per hot leg, or I

2) two RTD's bi'as applied. per hot leg with the failed RTD disconnected and the required BEAVER VALLEY - UNIT 2 /4 3-6

AMEN 0 MENT NO.

OP03Eb

NPF-73 TABLE 3.3-1 (Continued)

ACTION 10 - This Action is not used. l ACTION 11 - With less than the Minimum Number of Channels OPERABLE, operation l

may continue provided the inopegable channel is placed in the tripped condition within hour, l ACTION 12 - With the ncmber of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable !

channel to 0FCRABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STAND 8Y !

within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 39 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour. l ACTION 40 - a. With one of the diverse trip features (undervoltage or shunt trip attachment) of a reactor trip breaker inoperable, l restore the diverse trip feature to OPERA 3LE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in K)T j STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Neither breaker shall be i bypassed while one of the diverse trip features is inoperable j except for the time required for performing maintenance to 1 restore the breaker to OPERA 3LE status. '

b. With one reactor trip breaker inoperable as a result of something other than an inoperable diverse trip feature, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per specification 4.3.1.1,I,provided the other I channel is OPERABLE.

ACTION 44 - With less than the Minimum Number of annels OPERABLE, within i 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months determine by observation of the associated permissive I annunciator window (s) that the interlock is in its required j state for the existing plant condition, or apply Specification !

3.0.3.

BEAVER VALLEY - UNIT 2 3/4 3-7 Amendment No.

PROPOSEP

TABLE 4.3-1 REACTOR TRIP SYSTEN INSTRUMENTATION SURVEILLANCE REQUIREMENTS

< . CHANNEL MODES IN WillCH b N CHANNEL CHANNEL FUNCTIONAL SURVLILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUlHLO Manual Reactor Trip H.A. N.A. S/U(1),R(10) 1, 2, k '2O l z

' 1.

U 2. Power Range, Neutron Flux w

a. High Setpoint S D(2),N(3) -M- Q 1, 2 l and Q(6)

b. Low Satpoint S R S/U(1) 1(7), 2 1, 2

3. Power Range, Neutron Flux, M.A. R -M- Q g High Positive Rate e,

Power Range, Neutron Flux. N.A. R -M- Q 1, 2

.y 4.

High Negative Rate

5. Intermediate Range, S R S/U(1) .-Mt+)- 1 40,2SD h

Neutron Flux Source Range, Neutron Flux 5 R S/U(1),-M(43-Q@ 2,3,4

6. and S (Below P-10)

7. Overtemperature AT S R -M- Q 1, 2 S R -M- Q 1, 2

8. Overpower AT k 9. Pressurizer Pressure-Low S R -M- Q 1, 2 (Above P-7) 5 10. Pressurizer Pressure-High S R -M- Q 1, 2

er/ ace y- w,W Gv) 4

. _ _ . _ _ . . . ..____._..-_____-__m ____m_________________o<m.r-________

_ _ _ _ _ _ _- - ____-_m _ _ _ _ . --. _ _ _ _ _ _ _ _ _

TABLE 4.3-1 (Continued) m

@ REACTOR TRIP SYSTEM INSTRUMENTATION SURVflLLANCE REQUIREMENTS z E

< CHANNEL MODI b IN wilitil 4

CHANNEL CHANNEL FUNCTIONAL SURVi11iANCI u l;; FUNCTIONAL UNIT CHECK CALIBRATION TEST RI Qt11 Rl D

11. Pressurizer Water Level-High S R -M- Q 1, 7 E (Above P-7)

G -

w 12. Loss of Flow - Single Loop S R -M- Q l (Above P-8)

13. Loss of Flow - Two Loop S R 9

h 12 ^^- 1 (Above P-7 and below P-8)

% 14. Steam / Generator Water Level- S R -M- Q 1, 2 NR om Low-Low DY 15. DELETED.

%M V 16. Undervoltage - Reactor Coolant N.A. R M 1 Pumps (Above P-7)

17. Underfrequency - Reactor Coolant N.A. R M 1 Pumps (Above P-7)

18. Turbine Trip (Above.P-9)

A. Emergency Trip Header N.A. R S/U(1) 1, 2 Low Pressure

B. Turbine.Stop Valve Closure N.A. R S/U(1) 1, 2

{

19.' Safety Injection Input from ESF-N.A. N.A. R 1, 2 4 5 20. Reactor Coolant Pump Breaker N.A. N.A. R N.A.

g Position Trip (Above P-7) 21.' Reactor Trip Breaker N.A. N A. M(5,11) anti 5/U(1) 1, ? . h 4h O n n.a .. .a i a i. 8P 109 ic N.A. N.A. M(5) i,

, th .h O Replacs 4 at A G4)

TABLE 4.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS d -

g CHANNEL MODES IN WillCll' r- CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

{ _h FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED

' 23. Reactor Trip System Interlocks E A. Intermediate Range N.A. R 1, 2

-M(4)-Q s Neutron Flux, P-6 m

l- B. Power Range N.A. R -M(4)- g 1 Neutron Flux, P-8 C. Power Range N.A R 6g 1 j ,

Neutron Flux, P-9 i

g D. Power Range Neutron Flux, P-10 N.A. R

-M(9)-( 1, 2 q

$ E. Turbine Impulse N.A. R

-M(4)-8 1 sh m Chamber Pressure, P-13 9

1,2,k M M

24. Reactor Trip Bypass Breakers N.A. N.A. M(12),R(13) !

i lef ace l 4 w'A W e

=

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

NPF-73

TABLE 4.3-1 (Continued)

TABLE NOTATION

(/O -

With the reactor trip system breakers closed and the control rod I drive system capable of rod withdrawal.

.31 (1) - If not performed in previous days. l ,

~

(2) -

Heat balance only, aboveof 1$peettu RATED THERMAL POWER. l

,.pte Ctd (3) -

Compareincoretoexcoreaxialimbalanceabve1@ofRATEDTHERMAL POWER. Recalibrate if absolute difference > 3 percent.

(4) - (Notused) i,8,ttetfgIy,l f, t

(5) -

Each train tested every other month on a STAGGERED TEST BASIS.

(6) -

Neutron detectors may be excluded from CHANNEL CALIBRATION.

(7) -

Below P-10.

(8) -

Below P-6.

(9) -

R :;uired caly J.:n belcw Int:ricek Trip Satpcint.-(At ased) l (10) - The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervolta ,

Manual Reactor Trip Function.ge Theand testshunt shalltrip circuits also verifyfor thethe l OPERABILITY of the Bypass Breaker trip circuit (s).

(11)- The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

(12)- Local manual shunt trip prior to placing breaker in service.

(13) - Automatic undervoltage trip. --The specified surveillone: interval

-during th: fir:t ft:1 cycle ::y b; xtend:d tc coincid with cc,;plation of the first refueling cut:ge.

BEAVER VALLEY - UNIT 2 3/4 3-13 Amendment No.

PACPosGb

TABLE 3.3-3 z

k ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 9 1 e MINIMUM MINIMUM u

10TAL NO. CHANNELS CHANNELS APPLICABLE y FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. SAFETY INJECTION AND FEEDWATER ISOLATION na a. Manual Initiation 2 1 2 1,2,3,4 18

b. Automatic Actuation 2 1 2 1,2,3,4 13, 36 Logic and Actuation Relays

c. Containment 3 2 2 1,2,3 14 Pressure-High

g. d. Pressurizer 3 2 2 1, 2, M 14 l g Pressure-Low

$'" e. Steamline Pressure - Low 3/ loop 2/ loop 2/ operating 1, 2, $ 14 I y any loop loop 1.1 SAFETY INJECTION-TRANSFER FROM INJECTION TO THE RECIRCULATION MODE

a. Automatic Actuation 2 1 2 1,2,3,4 18 Logic Coincident with Safety Injection Signal

b. Refueling Water Storage 4 2 3 1, 2, 3, 4 16 Tank Level-Extreme Low Repl*ce 4 " A W e _ __ - . _ _ _ _ _ _ - _ - _ _ _ - - _ - - _ - - _ _ _ _ _ _ _ __ .. . _ _ _ _ _ _ _ _ _ - - - - _ - _ _ _ _ _ _ _ _ - _ _ _ _ _ _ - _ - _ _ _ _ - - _ - _ - _ _ _ .

lABLE 3.3-3 (Centinued) '

ENGINEEREO SAFEIY FEATURE ACIUATION SYSTEM INSTRuMENTAT10N m .

=

j

.c MINIMUM M TOTAL NO. CHANNELS CHANNELS APPLICABLI 8, FUNCT10NAL UNIT OF CHAIN 6ELS TO TRIP

{ OPERABLE MODES A_C I _IO_N_ u

4. STEAM LINE ISOLATION E -

4 a. Manual Initiation u

1. Individual 1/ steam line 1/ steam line 1/ operating 1, 2, 3, 41 <

steam line

2. System 2 sets I set 2 sets 1, 2, 3, in (2 switches / set)

b. Automatic Actuation 2 1 2 1, 2, 3 I1 u Logic and Actuation

. Relays L c. Containment Pressure 3 2 2 1, 2, 3 14

@** Intermediate-High-High

d. Steamline Pressure--Low 3/ loop 2/ loop 2/ operating 1, 2, h 14 l any loop loop

e. Steamline Pressure Rate -- High Negative 3/ loop:-( 2/ loop any loop 2/ operating loop 3h -+4-/y l

5. TURRINE TRIP & FEE 0 WATER ISOLATION - - _ -

h J. Steam Generator 3/ loop 2/ loop in 2/ loop in 1, 2, 3 14 Water Level-- any operating each operat-High-High, P-14 loop ing loop l ~ . _ - - - - >

ct W.

Automatic Actuation 2 1 2 1, 2 4/

Logic and Actuation Relays a %:lety injet t son See Item 1. above f or all Saf ety injen.t ion init sat ung f ont t sun . .u..I

.eyuise.cnts kep/ ace 4 w/W O)

Reptoce # wit 4 %)

m TABLE 3.3-3 (Continued)

ENGINEEREO SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 35

< m E MINIMUM E TOTAL'NO. CHANNELS CHANNELS APPLICABLE "

h FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACIl0N

6. LOSS OF POWER

=

4 a. 4.16kv Emergency Bus u

1. Undervoltage 2/4.16kw Bus 2/4.16kv Bus 2/4.16kv Bus 1, 2, 3, 4 33 (Trip Feed)

2. Undervoltage 1/4.16kw Bus 1/4.16kv Bus 1/4kv Bus 1, 2, 3, 4 33 (Start Diesel) g b. 4.16kw Emergency Bus 2/4.16kw Bus 2/ Bus 2/ Bus 1, 2, 3, 4 34 (Degraded Voltage)

c. 480 Volt Emergency Bus 2/480v Bus 2/8us 2/ Bus 1, 2, 3, 4 34 (Degraded Voltage)

7. AUXILIARY FEEDWATE M l

a. Automatic Actuation Logic 2 1 2 1, 2, 3 42 and Actuation Relays

b. Steam Gen. Water Level--

Low-Low

1. Start Turbine 3/sta. gen. 2/sta. gen. 2/sta. gen. 1, 2, 3 14 Driven Pump any sta. gen.

2. Start Motor 3/sta. gen. 2/sta. gen. 2/sta. gen. 1, 2, 3 . 14 Driven Pumps any 2 sta. gen.

c. Undervoltage-RCP (Start (3)-1/ bus 2 2 1, 2 14 Turbine Driven Pump)

(3Mnual initiation i. included in Spetititation 3./.l.2 I

NPF-73 MBLE 3.3-3 (Continued)

TABLE NOTATICN

@ rip function may be bypassed in this MODE below P-11.

l Q)hripFunctionautomaticallybypassedaboveP-11,andisbypassedbelow l P-11 when Safety Injection on low steam pressure is not manually bypassed.

ACTION STATEMENTS ,p f,,g 4 f fhn, m, m ACTION 13 - With the number of OPERABL annels one less than the Total Number of Channels, be in OT STANDBY within-MM-hours and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to-trwo-hours for surveillance testing per l Specification 4.3.2.1.1., rovided the other channel is operable.

ACTION 14 -

the number of OPERABLE Channels one less than the To Numbe Channels:

a. Below P-11 -12, place the inoperabl tripped conditio. annel in the' thin 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; r re the inoperable channel to OPERABLE s wit 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after exceeding P-11 or P-12; otherwise be t least HOT STANDBY within the following six hour .

b. Above P-11 an -12, place the inoperable c tripped el in the 1 tion within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; operation may c ue unti rformance of the next required CHANNEL FUNCTI ACTION 15 - (This ACTION is not used)

ACTION 16 -

h the number of OPERABLE Channels one less than the To Numb f Channels:

MNY a. Below P- ?-12, place the inoperabl bypass conditi annel in the restora the inopers .o channel to OPERABLE status within 24 ho after ex ng P-11 or P-12; other-wise be in at least HOT -

within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b. Above P-11 or P- , demonstrate that t nimum Channels OPERA 8LE re ement is met within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; o tion may continu th the inoperable channel bypassed an cha may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for testing cification 4.3.2.1.

BEAVER VALLEY - UNIT 2 g4g2

Insert 3 ACTION 14 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. The minimum channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

Insert 4 ACTION 16 -

With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met. One additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1.

Insert A ACTION 34 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

b. The Minimum channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of other channels per Specification 4.3.2.1.1.

,. ,NPF-73 UBLE 3. 3-3 (Continued)

ACTION 17 -

,i . , e.;; t?(This

".4CT/* n,pal mumis Channels wet u sedOP:RABLE, ocera * - y continue provided the contai - ;;m 3e = waa; . 0 %e ar.

'24"*'inid Lio5eQ.

. ACTION 18 - With the number of OPERABLE Channels one less than the Tetel fi,;,,% CL. /.s -P ini r d Ch = W , restore the inoperable channel to OPERABLE Off&dif Apwse mf status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANOBY within the l next6hoursangC,0LDSHUTDOWNwithinthefollowing30 hours.

m ACTION 33 - With the number of OPERABLE Channels one less than the Total Number of Channels, the Emergency Diesel Generator associated with the 4ky Bus shall be declared inoperable and the ACTION Statements for Specifications 3.8.1.1 or 3.8.1.2, as appropriate shall apply.

ACTION 34 - ,

[hiththenumberofOPERABLEChannelsonelesst Number of Channels, STARTUP and/or POWER OPERATION may proceed ,

Of /ace M- / until the performance of the next required Channel Functional Test provided the inoperable channel is placed in the tripped i pse,rf /)

conditionwithingoui4 _ _

ACTION 36 - The block of the automatic actuation logic introduced by a reset of safety injection shall be removed by resetting (closure) of the reactor trip breakers within.one hour of an inadvertent initiation of safety injection providing that all trip input signals have reset due to stable plant conditions. Otherwise, the requirements of ACTION Statement 13 shall have been met. ,

1 ACTION 37 - (This ACTION is not used) ;

ACTION 38 - With less than the Minimus Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window (s) (bistable status lights or computer checks) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3. ;

ACTION 41 - With the number of OPERA 8LE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

ACTION 42 - With the number of OPERA 8LE Channels one less than the minimum Channels OPERA 8LE requirement, be in at least HOT STAN08Y within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the f lowing-6 hours; however, one channel may be bypassed for up to hours l for surveillance testing per Specification 4.3.2.1.1 pro ided the other Channel is OPERA 8LE. p 1

ACTION 45 - With the number of OPERABLE channels one less than the Total i Number of Channels, restore the inoperable channel to OPERABLE l status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STAN0BY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . ;

)

BEAVER VALLEY - UNIT 2 g4g ,

1

5 m TABLE 4.3-2 7 4

h ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 9 SURVEILLANCE REQUIREMENTS h CHANNEL E MODES IN WillCil CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE f FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED E 1. SAFETY INJECTION AND FEEDWATER Z ISOLATION

~

a. Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4

b. Automatic Actuation Logic and N.A. N.A. M(2) 1, 2, 3, 4 Actuation Relays

c. Containment Pressure-High 5 R -M- & 1, 2, 3

d. Pressuriier Pressure--Low 5 R

-M- Q 1,2,3

[

%a

e. Steam Line Pressure--Low S R + Q 1, 2, 3 b 1.1 . SAFETY INJECTION-TRANSFER FROM INJECTION TO THE RECIRCULATION MODE

a. Automatic Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic, Coincident with Safety Injection Signal

b. Refueling Water Storage S R H 1,2,3,4 Tank Level-Extreme Low

+ M - __ . -7e

TABLE 4.3-2 (Continued) z m

< ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 7 9 SURVEILLANCE REQUIREMENTS d j!" CHANNEL MODES IN WlilCH E CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE CHECK CALIBRATION TEST 7 FUNCTIONAL UNIT REQUIRED E 2. CONTAllMENT SPRAY N a. Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4

b. Automatic Actuation and N.A. N.A. M(2) 1, 2, 3, 4 Logic Actuation Relays s

c. Containment Pressure--High- S R -ft- GL 1,2,3 l High w 3. CONTAINMENT ISOLATION

&w* a. Phase "A" Isolation wa h 1. Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4

2. Automatic Actuation Logic N.A. N.A. M(2) 1, 2, 3, 4 and Actuation Relays

3. Safety Injection See Functional Unit 1. above for all Safety Injection Surveillance Requirements.

b. Phase "B" Isolation

1. Manual Initation N.A. N.A. M(1) 1, 2, 3, 4

2. Automatic Actuation H.A. N.A. M(2) 1, 2, 3, 4 Logic and Actuation Relays

3. Containment Pressure--

High-High S R

% 1,2,3,4 l

=

co TABLE 4.3-2 (Continued) $i k ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 9 SURVEILLANCE REQUIREMENTS h CHANNEL MODES IN WHICH G CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE fFUNCTIONALUNIT CHECK CALIBRATION TEST REQUIRED E 4. STEAM LINE ISOLATION G

u a. Manual Initiation Individual

1. N.A. N.A.

M(1) 1, 2, 3

2. System N.A. N.A. M(1) 1, 2, 3

b. Automatic Actuation Logic and N.A. N.A. M(2) 1, 2, 3 Actuation Relays k.

o L

c. Containment Pressure--

Intermediate-High-High S R -M-Q 1,2,3 b

g'" d. Steam Line Pressure--Low S R -M- Q 1,2,3

e. Steamline Pressure Rate-High S Negative R -fPQ 1, 2, 3 S. TURBINE TRIP AND FEEDWATER ISOLATION-

a. Automatic Actuation Logic and N.A. N.A. M(2) 1, 2, 3 Actuation Relays

b. Steam Generator Water S R 1,2,3 Level--High-High, P-14 -M- Q l

c. Safety Injection See Functional Unit 1 above for all Safety injection Surveillance Requirements.

IABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEA10RE ACIUAIION SYSTEM INSTRUMENIATION Z 9 SURVEILLANCE REQUIREMENTS

?" w CHANNEL MODI 5 IN WillCil u G CHANNEL CHANNEL FUNCI10NAL SURviiiiANCL CHECK CALIBRATION RIQulkilj

[FUNCTIONALUNIT TEST E 6. LOSS Of POWER

-e u a. 4.16kv Emergency Bus N.A. R H 1, 2 l

1. Undervoltage (Trip feed)

2. Undervoltage (Start Diesel) N.A. R N 1, 2, 3, 4

. b. 4.16kw Emergency N.A. R H 1, 2 , 3, 4 Bus (Degraded Voltage) k

% c. 480 Volt Emergency Bus N.A. R H 1, / , 1, 4 (Degraded Voltage)

7. AUXILIARY FEEDWATER F

a. Automatic Actuation Logic and N.A. N.A. M(2) ' , 2, 3 Actuation Relays

b. Steam Generator Water Level--Low-Low

1. Start Turbine Driven S R -M-- @ 1, 2, 3 l Pump

2. Start Motor Driven S R -M- Q 1, 2, 3 l Pumps

c. Undervoltage - RCP (Start S R M 1, 2 Turbine Driven Pump)

[t[nual initiation is included in Specification 4./.l.2.

l

, TABLE 4.3-2 (Continued) h m

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUNENTATION SUI:VEILLAKL REQUINLRNIS f

w

@ CHANNEL H0 DES IN WillCH

@ FUNCTIONAL UNIT CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

, CHECK Call 8 RATION TEST REQUIRID

7. AUXILIARY FEEDWATER (continued) .

e+ d. Safety Injection (Start Motor- See 1 above (all SI surveillance requirements)

Driven Pumps)

e. Trip of Main N.A. N.A. R 1, 2, 3 Feedwater Pumps (Start Motor-Driven Pumps) hT

8. ENGINEERED SAFETY FEATURE INTERLOCKS

a. Reactor Trip, P-4 N.A. N.A. R(3) 1, 2, 3 v

b. Pressurizer Pressure, P-11 N.A. R -M- Q 1,2,3

c. Low-Low T,,g P-12 N.A. R -M- Q 1,2,3 k

I?- .

.?

___.m.- ___.__ , _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ . . - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ . _ _

! NPF-73

}

. : M. n : N

,. _u_ _ _ _:::

1 i

SNSEO 5 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION i

The OPERABILITY of the Reactor Protection System and Engineered Safety Feature Actuation System Instrumentation and interlocks ensure that 1) tne associated action and/or reactor trip will be initiated when the parameter moni-tored by each channel or combination thereof reaches its setpoint, 2) the l specified coincidence logic i: :: int:in:d, 3} : "!:f:nt r:dund:n:3 i; ::i-i -t:!.....y..... . . . . . . . . . . .

.. .. ... .. :;rvic; f;r t;;tinii ;r seintenance. M

3)-4) sufficient system functional capability is available from diverse parameters.

The OPERABILITY of these systems is required to provide the overall relia- !

I bility, redundancy, and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions. The inte-i 4 grated operation of each of these systems is consistent with the assumptions used-in the accident analyses. The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained com-

] parable to the original design standards. The periodic surveillance tests per-

)

formed at the minimum frequencies are suff,icient to demonstrate this capability.

The Engineered Safety Feature Actuation System Instrumentation Trip Set-points specified in Table 3.3-4 are the nominal values at which the bistables 5

i are set for each functional unit. A setpoint is considered to be adjusted consistent with the nominal value when the "as measured" setpoint is within the band allowed for calibration accuracy.

s 3

To accommodate the instrument drift assumed to occur between operational

{

tests and the accuracy to which setpoints can be measured and calibrated, i Allowable Values for the setpoints have. been specified in Table 3.3-4. Opera-tion with setpoints less conservative than the Trip Setpoint but within the !

Allowable analysis toValue is acceptable accommodate since an allowance has been made in the safety this error. !

An optional provision has been included for determining the OPERASILITY of a channel when its trip setpoint is found to exceed the Allowable Value. The methodology of this option utilizes the "as measured" deviation from the specified calibration point for rack and sensor components in conjunction with a statistical combination of the other uncer- ,

1 tainties of the instrumentation to measure the process variable and the uncer-

{ tainties in calibrating the instrumentation. In Equation 2.2-1, I + R +'S 1 TA, the interactive effects of the errors in the rack and the sensor, and the "as i

measured" values of the errors are considered. Z, as.specified in Table 3.3-4 in percent span, is the statistical summation of errors assumed in the analysis excluding those associated with the sensor and rack drift and the accuracy of their measurement. TA or Total Allowance is the difference, in percent span, between the trip setpoint and the value used in the analysis for the actuation R or Rack Error is the "as measured" deviation, in percent span , for the af fectec channel from the specified trip setpoint. S or Sensor Drift is either the "as measured' deviation of the sensor from its calibration point or the value spec -

fied in Table 3.3-4, in percent span, from the analysis assumptions. Use of-Equation 2.2-1 allows for a sensor drift factor, an increased rack drift factor; and provides a threshold value for REPORTA8LE EVENTS.

BEAVER VALLEY - UNIT 2

/g

- r-,e- - +

Ynsert 5 and sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance consistent with maintaining an appropriate level of reliability of the Reactor Protection and Engineered Safety Features instrumentation , and e Insert 6 Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP - 10271, !

" Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System," and supplements to that report as approved by the NRC and documented in the SER (letter to J. J. Sheppard from Cecil O. Thomas, dated February 21, 1985).

Jumpers and lifted leads are not an acceptable method for placing equipment in bypass as documented in the NRC safety evaluation report for this WCAP.

i

ATTACHMENT B Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 REVISION OF REACTOR TRIP AND ESF INSTRUMENTATION CHANGE TO QUARTERLY SURVEILLANCE TESTING A. DESCRIPTION OF AMENDMENT REQUEST The proposed amendment would modify the Reactor Trip System (RTS) and Engineered Safety Feature (ESP) instrumentation surveillance requirements to incorporate the applicable changes specified in WCAP-10271 and related supplements. Four specific changes were approved by the Nuclear Regulatory Commission for the RTS and ESFAS analog channels. These changes are limited to the specific RPS channels evaluated in the WCAP (including all supplements) and are subject to the conditions specified by the NRC.

1. The surveillance or test frequency may be changed from monthly to quarterly.

2. The time allowed for a channel to be inoperable or out of service in an untripped condition may be changed from one hour to six hours.

3. The time a channel in a functional group may be bypassed to perform testing may be increased from two to four hours.

This bypass time applies to either an inoperable channel when testing is done in the tripped mode or to the channel in test when testing is done in the bypass mode. The Allowed Outage Time for maintenance of a channel is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4. Routine channel testing may be performed in the bypassed condition instead of the tripped condition.

In addition, Attachment D provides a detailed description of the l changes. '

B. BACKGROUND In response to growing concerns of the impact of current testing l and maintenance requirements on plant operation, particularly as !

related to instrumentation systems, the Westinghouse Owners Group j (WOG) initiated a program to develop a justification to be used to revise generic and plant specific instrumentation technical specifications. Operating plants experienced many inadvertent reactor trips and safeguards actuations during performance of instrumentation surveillance, causing unnecessary transients and challenges to safety systems. Significant time and effort on the part of the operating staff was devoted to performing, reviewing, documenting and tracking the various surveillance activities, which in many instances seemed unwarranted based on the high B-1 l

Proposed Technical Spncification Changa No. 173/35 Page 2 reliability of the equipment. Significant benefits for operating plants appeared to be achievable through revision of l instrumentation test and maintenance requirements.

On February 3, 1983, the WOG submitted WCAP-10271, " Evaluation of l Surveillance Frequencies and Out of Service Times for the Reactor ;

Protection Instrumentation System" (Reference 3) to the NRC as the first step in gaining approval of the instrumentation program. WCAP-10271 documents the justification to be used to justify revisions to plant specific technical specifications.

The justification consists of the deterministic and numerical evaluation of the effects of particular technical specification ,

changes with consideration given to such things as safety, I equipment requirements, human factors and operational impact. '

The objective is to reach a balance in which safety and i

operability are ensured. The technical specification revisions ,

evaluated were increased test and maintenance times, less l frequent surveillance, and testing in bypass. l

' I In July 1983, the NRC requested additional information from the l WOG (letter to J. J. Sheppard from Cecil O. Thomas, dated July 28, 1983, Reference 4) required for continued review. The i WOG responded in October 1983 (letter OG-106, dated October 4, 4 I

1983, Reference 5) with responses to the NRC concerns and Supplement 1 to WCAP-10271 .(Reference 2) which contains information in addition to that in WCAP-10271 (Reference 1).

Specifically, Supplement 1 demonstrates the applicability of the justification contained in WCAP-10271 to Reactor Trip Systems (RTS) for two, three and four loop plants with either relay or solid state logic. Additionally, this supplement extends the evaluation to topics not addressed in the original WCAP such as the interdependence of surveillance intervals and hardware failure rates.

In February 1985, the NRC issued the SER (letter to J. J.

Sheppard from Cecil O. Thomas, dated February 21, 1985, Reference

6) for WCAP-10271 and Supplement 1. The SER approved quarterly testing, 6 hours to place a failed channel in a tripped mode, I

increased Allowed Outage Times for test and maintenance, and testing in bypass for analog channels of the Reactor Trip System with a stipulation that the quarterly testing had to be conducted on a staggered basis.

The SER specifically stated that for analog channels shared by the RTS and Engineered Safety Features Actuation System (ESFAS) the approved relaxations applied only to the RTS function. In a letter dated July 24, 1985, from the NRC to L. D. Butterfield, Chairman of the WOG (Reference 10), they provided comments on the draft " Guidelines for Preparing Submittals Requesting Revision of Reactor Protection System Technical Specification." In Enclosure 3 of the letter, they provided a broader relaxation of the surveillance for shared components, subject to proper annotation to the surveillance requirements.

B-2

l \

l Proposed Tcchnical Specification Changa No. 173/35 Page 3 l

On March 20, 1986, the WOG submitted WCAP-10271, Supplement 2,

" Evaluation of Surveillance Frequencies and Out of Service Times for the Engineered Safety Systems Actuation System" (Reference 7). On May 12, 1987, the WOG submitted WCAP-10271, Supplement 2, Revision 1, (References 8 and 9). Supplement 2 and Supplement 2, i Revision 1, specifically demonstrated the applicability of the justification contained in WCAP-10271 to the Engineered Safety i Features Actuation System for two, three and four loop plants I with either relay or solid state systems.

In Appendix D of WCAP-10271, Supplement 2, Revision 1, the l results of the evaluation for extending the Allowed Outage Times I for the test and maintenance of the reactor trip breakers and the l logic cabinets were presented. I In February 1989, the NRC issued the SER (letter to Roger A.

Newton from Charles E. Rossi, dated February 22, 1989, Reference

11) for WCAP-10271 Supplement 2 and Supplement 2, Revision 1.

The SER approved quarterly testing, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months to place a failed channel in a tripped mode, increased Allowed Outage Time for test and maintenance and testing in bypass for analog channels of the i ESFAS. The ESFAS functions approved in the SER were those ;

presented in Appendix Al of the reference WCAPs. These functions I are all included in the Westinghouse Standard Technical Specifications. Staggered testing was not required for ESFAS analog channels and the requirement was removed from the RTS l analog channels. 1 In their letter dated April 30, 1990 (Reference 12), the NRC l issued the Supplemental SER (SSER) for WCAP-10271, Supplement 2, and supplement 2, Revision 1. The SSER approved surveillance ,

test interval (STI) and allowed outage time (AOT) extensions for i the ESFAS functions that were included in Appendix A2 of WCAP-10271, Supplement 2, Revision 1. The functions approved are ;

associated with the Safety Injection, Steam Line Isolation, Main Feedwater Isolation, and Auxiliary Feedwater Pump Start signals.

The configurations contained in the Appendix A2 are those that are not contained in the Westinghouse Standard Technical Specifications. The SSER also approved the extended AOTs for the Reactor Trip System Actuation Logic that were requested in WCAP-10271, Supplement 2, Revision 1, Appendix D.

With the issuance of the SER and SSER, the relaxations for the analog channels of the RTS and ESFAS are now the same and the special conditions applied to shared analog channels are no longer applicable. The AOTs for test and maintenance of RTS and ESFAS Actuation Logic are also now the same.

The three SERs (References 6, 11 and 12) together approved all relaxations requested by the WOG in the WCAP-10271 program except the extensions requested in Supplement 2, Revision 1, Appendix D for the reactor trip breakers and the Main Feedwater Isolation on T-cold Low coincident with Feedwater Flow Hi that was included in Appendix A2. The NRC has indicated that they are not prepared to B-3

Proposed Technical Spscification Changa No. 173/35 i Page 4 consider relaxations to the reactor trip breakers as part of this program and the T-cold Low coincident with Feedwater Flow Hi function is no longer used on any plant. The NRC review of the WCAP-10271 program is therefore considered to be complete. The

-final WCAP in the series, WCAP-10271, Supplement 2, Revision 1, was issued as an approved WCAP with the SERs included in June, 1990.

C. JUSTIFICATION i

l WCAP-10271 and Supplement 1, Supplement 2 and Supplement 2, I Revision 1, documents the justification for revision to plant specific technical specifications. The justification consists of the deterministic and numerical evaluation of the effects of particular technical specification changes with consideration given to safety, equipment requirements, human factors and operational impact. The objective is to reach a balance in which ,

safety and operability are ensured. The technical specification j revisions evaluated were increased test and maintenance times, j less frequent surveillance, and testing in bypass. The NRC l approved WCAP-10271 with the issuance of separate Safety l Evaluation Reports (SER's), one for the Reactor Trip System (RTS) l Instrumentation, one for the Engineered Safety Feature Actuation l System (ESFAS) Instrumentation, and one for the additional ESFAS Instrumentation not included in the Standard Technical Specifications (STS).

i D. SAFETY ANALYSIS In WCAP-10271 and its supplements, the WOG evaluated the impact of the proposed STI and AOT changes on core damage frequency and public risk. The NRC staff concludes in its evaluation of the WOG evaluation that an overall upper bound increase of the core damage frequency due to the proposed STI/AOT changes is less than 6 percent for Westinghouse Pressurized Water Reactor (PWR) plants. The NRC Staff also concluded that actual core damage ,

frequency increases for individual plants are expected to be substantially less than 6 percent. The NRC staff considered this i core damage frequency increase to be small compared to the range ;

of uncertainty in the core damage frequency analyses and is therefore acceptable.

The NRC Staff conc. ded in addition that a staggered test strategy need not be implemented for ESFAS analog channel testing and is no longer required for RTS analog channel testing. This conclusion was based on the small relative contribution of the analog channels to RTS/ESFAS unavailability, process parameter signal diversity and normal operational testing sequencing.

1 The NRC determined that the requirement to routinely verify permissive status is a different consideration than the availability of trip or actuation channels which are required to B-4 i

Proposed Technical Spncification Change No. 173/35 Page 5 change state on the occurrence of an event and for which the function availability is more dependent on the surveillance interval. The definition of the channel check includes comparison of the channel status with other channels for the same parameter. For the Reactor Trip System Interlocks, the change from monthly surveillance requirement to at least once every 18 months is therefore justified.

The proposed changes are consistent with the NRC staff's letters dated February 21, 1985, February 22, 1989, and April 30, 1990, to the WOG regarding evaluation of WCAP-10271, WCAP-10271 Supplement 1, WCAP-10271 Supplement 2, and WCAP-10271 Supplement 2, Revision 1. The Staff has stated that approval of these changes is contingent upon confirmation that certain conditions are met. It is our interpretation that conditions imposed in the SER for WCAP-10271 and WCAP-10271 Supplement 1, for the RTS instrumentation shall also be applied to the ESFAS where appropriate.

The following changes have been incorporated:

(a) Changes described in revised Technical Specification 3/4.3.1 include:

(i) The Surveillance Test Interval in Table 4.3-1 for functional unit 23, Reactor Trip System Interlocks, Channel Functional Test, is changed from "M" to "R" (at least once per 18 months) for each of the five interlocks, This was not part of the WCAP but was granted by the NRC (Reference 10) without request.

(ii) Increase in surveillance intervals for Reactor Trip System (RTS) channel functional tests from once per month to once per quarter.

(iii) Increase in the time that an inoperable RTS channel may be maintained in an untripped condition from i hour to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

(iv) Increase in the time that an inoperable RTS channel may be bypassed to allow testing of another channel in the same function from 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

(v) Allow RTS analog channels to be tested in a bypassed condition instead of a tripped condition.

(vi) In Table 3.3-1, Action 1 has been modified to allow 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months to restore an inoperable channel to operable status before requiring shutdown to hot standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to allow bypass of a channel for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing, provided the other channel is operable. This action statement is B-5

Proposcd Tcchnical Sp cification Change No. 173/35 Page 6 applicable to Functional Units 19 (Safety Injection Input From ESF) and 22 (Automatic Trip Logic, in Modes 1 and 2).

(b) Changen described in revised Technical Specification 3/4.3.2 include:

(i) Increase in surveillance intervals for Engineered Safety Feature Actuation System (ESFAS) analog channel operatienal tests from once per month to once per quarter. :

(ii) Increase in the time that an inoperable (ESFAS) channel may be maintained in an untripped condition from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

(iii) Increase in the time that an inoperable (ESFAS) channel may be bypassed to al low testing of another channel in the same function fror 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

(iv) Allow ESFAS analog channels to se tested in a bypassed condition instead of a tripped condition.

(v) Increase the test and maintenaaca Allowed Outage Times (AOTs) for the ESFAS logic and L31ays.

(c) Revisions to the 3/4.3.1 and 3/4.3.2 Reactor Trip and Engineered Safety Features Actuation System Instrumentation Bases.

Acceptance of these proposed-technical specification changes is based on a satisfactory response to the conditions imposed by the NRC SER's. These conditions are provided here along with the applicable response:

Condition 1 -

The RTS SER requires the use of a staggered test plan for the Reactor Protection System (RPS) channels changed to the quarterly test frequency.

Response 1 -

This requirement was not required for the ESFAS channels and was also removed from the RTS channels in the ESFAS SER.

Condition 2 - The RTS SER requires that plant procedures require a common cause evaluation for failure in the RPS channels changed to the quarterly test frequency and additional testing for plausible common cause failures.

Response 2 - The plant has confirmed the existence of maintenance procedures which require the evaluation of a failure of plant components including any RPS channel in the quarterly test program to dete:.'i.ne if that failure could be a common cause failure. Prior to amendment implementation, these procedures B-6

Proposed Technical Spncification Change No. 173/35 Page 7 l

will address the appropriate remedial action, such as additional testing of the other channels in that function, if the failure is determined to be a plausible common cause failure. Failures such as instrument drift and power supply failures to a single channel are not considered common cause failures. Additional testing is not required for these types of failures. Additionally, failures of the sort that are " announced" through control room alarms or t annunciation or through other readily observed means need not be ,

considered to be plausible conson cause problems and do not !

require additional testing. Any additional testing that is performed would be consistent with the types of problems to be found. For example, if the failure can not be detected by standard channel tests, testing other than the standard channel test would be performed.

Condition 3 - The RTS SER requires installed hardware capability i for testing in the bypass mode.

Response 3 -

Testing in bypass will only be performed when ,

t installed hardware and applicable Action statements are available l to allow testing in bypass without reliance on lifted leads or ,

jumpers (other than to connect test equipment). The containment pressure high-high and refueling water storage tank level functions are the only functions which currently have installed l bypass capability. :

I l

Condition 4 - The RTS SER involves channels that provide input to both the RTS and the ESFAS.

Response 4 -

Prior to issuance of the ESFAS SER, the NRC was concerned about the potential for confusion regarding dual function channels. The ESFAS SER has since been issued and all of the relaxations for the RTS analog channels are applicable to the ESFAS analog channels, therefore, this is no longer a concern. j l

Condition 5 -

The RTS and ESFAS SERs require confirmation that I the instrument setpoint methodology includes sufficient adjustments to offset the drift anticipated as a result of less frequent surveillance. The setpoint methodology allowance for drift is chosen to conservatively bound any anticipated drift over a one month surveillance interval. The Westinghouse Owners Group does not have sufficient data to conclude that the setpoint !

allowance also conservatively bounds any anticipated drift over a quarterly surveillance interval.

l Response 5 -

Duquesne Light Company has reviewed the instrument calibration "as found" and "as left" records based on the monthly procedures perforned during 1992. This review confirmed that the setpoint drift has been shown to remain within the existing allowance and that extension of the surveillance to quarterly :

intervals will not result in any significant increase in {

out-of-tolerance conditions due to drift. '

l B-7

l Proposed Technical Specification Change No. 173/35 Page 8

)

Condition 6 -

The ESFAS SER requires that the plant specific applications must confirm the applicability of the generic analyses to the plant.

Response 6 - The WCAP methodology addresses two loop, three loop and four loop plants with relay or solid state systems. The changes to the BV-1 and BV-2 Technical Specifications reflect the functions that have been evaluated and documented in WCAP-10271 l and Supplement 1, Supplement 2, and Supplement 2 Revision 1 and ;

the NRC safety evaluations for these documents. l Based on the above considerations, these changes reflect the I application of methodologies recognized by the NRC and Industry as providing a sufficient margin of safety. Therefore, the proposed changes are considered to be safe and will not reduce l the safety of the plant.

E. NO SIGNIFICANT HAZARDS EVALUATION The no significant hazard considerations involved with the proposed amendment have been evaluated, focusing on the three standards set forth in 10 CFR 50.92(c) as quoted below:

The Commission may make a final determination, pursuant to the procedures in paragraph 50.91, that a proposed amendment to an operating license for a facility licensed under paragraph 50.21(b) or paragraph 50.22 or for a testing facility involves no significant hazards consideration, if operation of the facility in accordance with the proposed amendment would not:

(1) Involve a significant increase in the probability or 1 consequences of an accident previously evaluated; or l (2) Create the possibility of a new or different kind of i accident from any accident previously evaluated; or '

(3) Involve a significant reduction in a margin of safety.

The following evaluation is provided for the no significant hazards consideration standards.

i

1. Does the change involve a significant increase in the probability or consequences of an accident previously evaluated?

The determination that the results of the proposed changes are within all acceptable criteria was established in the SER(s) prepared for WCAP-10271, WCAP-10271 Supplement 1, WCAP-10271 Supplement 2 and WCAP-10271 Supplement 2, Revision 1 issued by letters dated February 21, 1985, February 22, 1989 and April 30, 1990. Implementation of the proposed changes is expected to result in an acceptable B-8

Proposed Technical Specification Change No. 173/35 Page 9 increase in total Reactor Protection System yearly unavailability. This increase, which is primarily due to less frequent surveillance, results in an increase of similar magnitude in the probability of an Anticipated ,

Transient Without Scram (ATWS) and in the probability of core melt resulting from an ATWS and also results in a small increase in Core Damage Frequency (CDF) due to Engineered ,

Safety Features Actuation System unavailability.

Implementation of the proposed changes is expected to result in a significant reduction in the probability of core melt from inadvertent reactor trips. This is a result of a :

reduction in the number of inadvertent reactor trips (0.5 -

fewer inadvertent reactor trips per unit per year) occurring during testing of RPS instrumentation. This reduction is i primarily attributable to testing in bypass and less frequent surveillance.

i The reduction in advertent core melt frequency is sufficiently large to counter the increase in ATWS core melt probability resulting in an overall reduction in total core melt probability.

The values determined by the WOG and presented in the WCAP for the increase in CDF were verified by Brookhaven National Laboratory (BNL) as part of an audit and sensitivity analyses for the NRC Staff. Based on the small value of the increase compared to the range of uncertainty ir the CDF, '

the increase is considered acceptable.

Changes to Surveillance Test Frequencies for the Reactor '

Trip System interlocks do not represent a significant reduction in testing. The currently specified test interval for interlock channels allows the surveillance requirement to be satisfied by verifying that the permissive logic is in its required state using the annunciator status light. The surveillance, as currently required, only verifies the status of the permissive logic and does not address verification of channel setpoint or operability. The setpoint verification and channel operability are verified l after a refueling shutdown. The definition of the channel !

check includes comparison of the channel status with other !

channels for the same parameter. The requirement to routinely verify permissive status is a different consideration than the availability of trip or actuation channels which are required to change state on the occurrence of an event and for which the function availability is more dependent on the surveillance interval. The change in surveillance requirement to at least once every 18 months does not therefore represent a :

significant change in channel surveillance and does not involve a significant increase in unavailability of the Reactor Protection System.

B-9

Proposed Technical Spscification Change No. 173/35 i Page 10 The proposed changes do not result in an increase in the severity or consequences of an accident previously evaluated.

l Implementation of the proposed changes affects the l probability of failure of the RPS but does not alter the i manner in which protection is afforded nor the manner in which limiting criteria are established.

Therefore, the proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.

I

2. Does the change create the possibility of a new or different kind of accident from any accident previously evaluated? ;

The proposed changes do not result in a change in the manner in which the Reactor Protection System provides plant protection. No change is being made which alters the functioning of the Reactor Protection System (other than in a test mode). Rather the likelihood or probability of the Reactor Protection System functioning properly is affected l as described above. Therefore, the proposed changes do not create the possibility of a new or different kind of i accident nor involve a reduction in a margin of safety as ;

defined in the Safety Analysis Report, j The proposed changes do not involve hardware changes except ,

those necessary to implement testing in bypass. Some l existing instrumentation is designed to be tested in bypass and current technical specifications allow testing in bypass. Testing in bypass is also recognized by IEEE ,

Standards. Therefore, testing in bypass has been previously l approved and implementation of the proposed change for !

testing in bypass does not create the possibility of a new or different kind of accident from any previously evaluated. Furthermore, since the other proposed changes do i not alter the functioning of the RPS, the possibility of a new or different kind of accident from any previously evaluated has not been created.

l

3. Does the change involve a significant reduction in a margin of safety?

The proposed changes do not alter the manner in which safety limits, limiting safety system setpoints or limiting conditions for operation are determined. The impact of reduced testing other than as addressed above is to allow a longer time interval over which instrument uncertainties (e.g., drift) may act. Experience has shown that the initial uncertainty assumptions are valid for reduced testing.

B-10

Proposed Technical Spacification Change No. 173/35 Page 11 ;

i Implementation of the proposed changes is expected to result I in an overall improvement in safety by: I

a. Less frequent testing will result in fewer inadvertent reactor trips and fewer actuations of Engineered Safety Feature Actuation System components.

b. Improvements in the effectiveness of the operating i staff in monitoring and controlling plant operation.

This is due to less frequent distraction of. the operator and shift supervisor to attend to instrumentation testing.

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

F. NO SIGNIFICANT HAZARDS CONSIDERATION DETERMINATION l Based on the considerations expressed above, it is concluded that the activities associated with this license amendment request satisfies the no significant hazards consideration standards of 10 CFR 50.92(c) and, accordingly, a no significant hazards consideration finding is justified.

)

i l

B-11

Proposed Technical Spacification Changa No. 173/35 Page 12 l

REFERENCES

1. WCAP-10271, " Evaluation of Surveillance Frequencies and Out of j Service Times for the Reactor Protection Instrumentation System," l January 1983. l

)

2. WCAP-10271 Supplement 1, " Evaluation of Surveillance Frequencies !

and Out of Service Times for tha Reactor Protection Instrumentation System," July 1983.

3. Letter (OG-86) from J. J. Sheppard (WOG) to H. R. Denton (NRC) dated February 3, 1983 (WCAP-10271 submittal).

4. Letter from C. O. Thomas (NRC) to J. J. Sheppard (WOG) dated July 28, 1983 (NRC Request Number 1 for Additional Information on l WCAP-10271). I

5. Letter (OG-106) from J. J. Sheppard (WOG) to C. O. Thomas (NRC) !

dated October 4, 1983 (WCAP-10271 Supplement 1 and question l response submittal).

6. Letter from C. O. Thomas (NRC) to J. J. Sheppard (WOG) dated j February 21, 1S85 (NRC safety evaluation for WCAP-10271).

7. WCAP-10271 Supplement 2, " Evaluation of Surveillance Frequencies and Out of Service Times for the Engineered Safety Features Actuation System," February 1986.

8. WCAP-10271-P-A Supplement 2, Revision 1 " Evaluation of.

Surveillance Frequencies and Out of Service Times for the Engineered Safety Features Actuation System," June 1990.

9. Letter (OG-87-15) from Roger A. Newton (WOG Chairman) to R. W.

Starosticki (NRC) dated May 12, 1987 (WCAP-10271 Supplement 2, Revision 1 submittal).

l 10. Letter from H. R. Denton (NRC) to L. D. Butterfield (WOG Chairman) dated July 24, 1985 (Comments to Guidelines).

l

11. Letter from Charles E. Rossi (NRC) to Roger A. Newton (WOG) dated l February 22, 1989 (NRC Safety Evaluation for WCAP-10271 Supplement 2 and Supplement 2, Revision 1).

12. Letter from Charles E. Rossi (NRC) to G. T. Goering (WOG) dated April 30, 1990 (NRC Supplemental Safety Evaluation for WCAP-10271 Supplement 2, Revision 1).

B-12 l

l

2

" - ATTACHMENT C-1 Beaver Valley Power Station, Unit No. 1 Proposed Technical Specification Change No. 173 j TYPED PAGES Applicable Typed Pages l

ATTACHMENT TO LICENSE AMENDMENT NO.

FACILITY OPERATING LICENSE NO. DPR-66 DOCKET NO. 50-334 i

Replace the following pages of Appendix A, Technical Specifications, with the enclosed pages as indicated. The revised pages are identified by amendment number and contain vertical lines indicating !

the areas of change. l Remove Insert 3/4 3-2 3/4 3-2 3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 3/4 3-6 3/4 3-6 i 3/4 3-7 3/4 3-7 3/4 3-11 3/4 3-11 l 3/4 3-12 3/4 3-12 3/4 3-12a 3/4 3-13 3/4 3-13 3/4 3-15 3/4 3-15 3/4 3-18 3/4 3-18 3/4 3-20 3/4 3-20 3/4 3-21 3/4 3-21 3/4 3-29 3/4 3-29 3/4 3-29a 3/4 3-29a 3/4 3-30 3/4 3-30 3/4 3-31 3/4 3-31 3/4 3-31a 3/4 3-31a 3/4 3-31b deleted B 3/4 3-1 B 3/4 3-1 B 3/4 3-la B 3/4 3-la B 3/4 3-lb i

l 1

i (Proposed Wording) i

t -

~

TABLE 3.3-1 O

REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM $

TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. Manual Reactor Trip 2 1 2 1 , 3(3) 12 4(3 and 5(3)

2. Power Range, Neutron Flux

a. High Setpoint 4 2 3 1, 2 2

b. Low Setpoint 4 2 3 1(1) , 2 2

3. Power Range, Neutron Flux 4 2 3 1, 2 2 High Positive Rate

4. Power Range, Neutron Flux 4 2 3 1, 2 2 High Negative Rate

5. Intermediate Range, Neutron 2 1 2 1(1) 2, 3(3) 3 Flux 4(3),and 5(3),

6. Source Range, Neutron Flux (Below P-10)

a. Startup 2 1 2 2(2) 3(3) 4 !

4(3),and 5(3) I

b. Shutdown 2 0 1 3, 4, and 5 5

7. Overtemperature AT 3 2 2 1, 2 7 g

8. Overpower AT 3 2 2 1, 2 7 l

9. Pressurizer Pressure-Low 3 2 2 1, 2 7 (Above P-7)

BEAVER-VALLEY - UNIT 1 3/4 3-2 Amendment No.

(Proposed Wording)

h. _ _ _ _ _ _ - ., ._ . . . . _.m --..s._ __ m _ _ _ . _ _ _ _ .. _ _ _ _ _ _ . _ _ . _ _ _ _ . _

1 TABLE 3.3-1 (Continued) 0 REACTOR TRIP SYSTEM INSTRUMENTATION lc 5

MINIMUM m TOTAL NO. CHANNELS CHANNELS APPLICABLE 2 FUNCTIONAL UNIT OF CPANNELS TO TRIP OPERABLE MODES ACTION

18. Turbine Trip (Above P-9)

A. Auto Stop Oil Pressure 3 2 2 1 7 B. Turbine Stop Valve 4 4 4 1 8 Closure

19. Safety Injection Input 2 1 2 1, 2 1 from ESF

20. Reactor Coolant Pump 1/ breaker 2 1/ breaker 1 11 Breaker Position Trip per (Above P-7) operating loop

21. Reactor Trip Breakers 2 1 2 1 ,

(3) , 40 2 1 2 4(3 ,5 3) 39

22. Automatic Trip Logic 2 1 2 1 ,

(3) , 1 2 1 2 4I ,5 3) 39 ,

23. Reactor Trip System Interlocks

'A. Intermediate Range 2 1 1 2 3 Neutron Flux, P-6 B. Power Range 4 2 3 1 12 Neutron Flux, P-8 C.~ Power Range 4 2 3 1 12 ';

Neutron Flux, P-9 D. Power Range 4 2 3 1 12 Neutron Flux, P-10 E. Turbine Impulse 2 1 1 1 12 Chamber. Pressure, P-13

- BEAVER VALLEY - UNIT 1 3/4 3-4 Amendment No.

(Proposed Wording)'

^

)

i DPR-66 TABLE 3.3-1 (Continued) 4 l

. TABLE NOTATION 4

(1) Trip function may be manually bypassed in this Mode above P-10.

! (2) Trip function may be manually bypassed in this Mode above P-6. ;

(3) With the reactor trip system breakers in the closed position and l .

the control rod drive system capable of rod withdrawal.

! ACTION STATEMENTS ACTION 1 - With the number of OPERABLE Channels one-less than the

! Minimum Channels OPERABLE requirement, restore the i

inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months l or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; i

however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.1.1.1, provided the other channel is OPERABLE.

ACTION 2 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER ,

OPERATION may proceed provided the following conditions are satisfied: i

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , ,

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1, and

c. Either, THERMAL POWER is restricted to less than or equal to 75 percent of RATED THERMAL POWER and the Power Range Neutron Flux setpoint is reduced to less than or equal to 85 percent of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification 4.2.4.c.

ACTION 3 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a. Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 setpoint.

b. Above P-6 but below 5 percent of RATED THERMAL POWER, l restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 5 percent of l RATED THERMAL POWER.

c. Above 5 percent of RATED THERMAL POWER, POWER l OPERATION may continue.

BEAVER VALLEY - UNIT 1 3/4 3-5 Amendment No.

(Proposed Wording)

l DPR-66 TABLE 3,3-1 (Continued)

ACTION 4 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement l

and with the THERMAL POWER level:

l a. Below P-6, restore the inoperable channel to OPERABLE l status prior to increasing THERMAL POWER above the P-6 setpoint.

b. Above P-6, operation may continue.

ACTION 5 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN l requirements of Specification 3.1.1.1 or l

Specification 3.1.1.2, as applicable within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

ACTION 6 - Not Applicable. ,

ACTION 7 - With the number of OPERABLE channelsI4) one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

I a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,.and The Minimum Channels OPERABLE requirement is met; i b.

l however, the inoperable channel may be bypassed for up l

to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

ACTION 8 - With the number of OPERABLE channels one less than the Total Number of Channels and with the THERMAL' POWER level above P-7, place the inoperable channel in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; operation may l continue until performance of the next required l CHANNEL FUNCTIONAL TEST.

ACTION 9 - Not applicable. l l

ACTION 10 - Not applicable.

(4) An OPERABLE hot leg channel consists of: 1) three RTDs per hot I leg, or 2) two RTDs per hot leg with the failed RTD disconnected.

l and the required bias applied.

I I

I i

BEAVER VALLEY - UNIT 1 3/4 3-6 Amendment No. !

(Proposed Wording) I l

1

DPR-66 TABLE 3.3-1 (Continuedl ACTION 11 - With less than the Minimum- Number of Channels l OPERABLE, operation may continue provided the inoperable channel is placed in the-tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . l ACTION 12 - With the number of channels OPERABLE one less than :

required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status ;

within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 39 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months j or open the reactor trip breakers within the next hour. ,

ACTION 40 - a. With one of the diverse trip features (undervoltage or shunt trip attachment) of a reactor trip breaker inoperable, restore the diverse trip feature to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in s HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Neither l l breaker shall be bypassed while one of- the ,

diverse trip features is inoperable except for '

. the time required for performing maintenance to restore the breaker to OPERABLE status. '

b. With one reactor trip breaker inoperable as a result of something other than an inoperable diverse trip feature; be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance t testing per Specification 4.3.1.1.1, provided the l other channel is OPERABLE.

1 BEAVER VALLEY - UNIT 1 3/4 3-7 Amendment No.

(next page is 3/4 3-9)

(Proposed Wording)

TABLE 4.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS e N

Channel Modes in Which &

i Channel Channel Functional Surveillance m Reauired Functional Unit Check Calibration Test

1. Manual Reactor Trip N.A. N.A. y,g, S/{f1) ,

2. Power Range, Neutron Flux

a. High Setpoint S D(2) ,g(3) Q 1, 2 l and Q(6)

b. Low Setpoint S N.A. S/U(1) 2

3. Power Range, Neutron Flux, N.A. R Q 1, 2 High Positive Rate

4. Power Range, Neutron Flux, N.A. R Q 1, 2 High Negative Rate

5. Intermediate Range, Neutron S N.A. S/U(1) 1 2 4(14) 3(14),

Flux , 5(14)

6. Source Range, Neutron Flux N.A. N.A. S (1) , 2, 3, 4~

(Below P-10) Q{g) and 5

7. Overtemperature AT S R Q 1, 2

8. Overpower AT S R Q 1, 2

9. Pressurizer Pressure-Low S R Q 1, 2

10. Pressurizer Pressure-High S R Q 1, 2

11. Pressurizer Water Level-High S R Q 1, 2 BEAVER VALLEY - UNIT 1 3/4 3-11 Amendment No.

(Proposed Wording)

TABLE 4.3-1 (Continued) :

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS O Channel Modes in Which &

Channel Channel Functional Surveillance m Functional Unit Check Calibration Test Recuired

12. Loss of Flow - Single Loop S R Q 1

13. Loss of Flow - Two Loops S R Q 1

14. Steam / Generator Water S R Q 1, 2 Level-Low-Low

15. Steam Feedwater Flow S R Q 1, 2 Mismatch and Low Steam Generator Water Level

16. Undervoltage-Reactor Coolant N.A. R M 1 Pumps

17. Underfrequency-Reactor N.A. R M 1 Coolant Pumps

18. Turbine Trip

a. Auto Stop Oil Pressure N.A. N.A. 1, 2

b. Turbine Stop Valve N.A. N.A. S/U((1)

S/U 1) 1, 2 Closure

19. Safety Injection Input from N.A. N.A. R 1, 2 ESF

20. Reactor Coolant Pump Breaker N.A N.A. R N.A Position Trip

21. Reactor Trip Breaker N.A. N.A. M(5, 11) 1 2 and S/U(1) 4(14f,3(14)5(14)

BEAVER VALLEY - UNIT 1 3/4 3-12 Amendment No.

(Proposed Wording)

l 1

i TABLE 4.3-1 (Continued) e REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS %I i Channel Modes in Which$ !

Channel Channel Functional Surveillance ,

Functional Unit Check Calibration Test Recuired '

22. Automatic Trip Logic N.A. N.A. M(5) 1 3(14) 4(1gj , 5(14) '

23. Reactor Trip System Interlocks A. P-6 N.A. N.A. R 1, 2 B. P-8 N.A. N.A. R 1 C. P-9 N.A. -N.A. R 1 D. P-10 N.A. N.A. R 1 E. P-13 N.A. R R 1

24. Reactor Trip Bypass. Breakers N.A.- N.A.. M(12) 1 2 3(14) ,

R(13), 4(14j ,

5(14j S/U(1)

I e

b BEAVER VALLEY - UNIT:1 3/4 3-12a - Amendment.No. !

.(Proposed Wording)

-i

_ . . _ . . _ _ _ _ _ _ . _ _ _ ____..__.._._.______._...__________...__.___m.. ___..____m.m__.______ _ _ . , , - . . _ _ . . _ . _ , . _ . . _ , . .

m , - --4,_.,m- .-..__-_~.m.,_..__.s. . ~ . . . . . . . . , . . - . _ - . , - . . . .

DPR-66 TABLE 4.3-1 (Continued)

NOTATION (1) -

If not performed in previous 31 days. l (2) -

Heat balance only, above 15 percent of RATED THERMAL POWER. l (3) -

Compare incore to excore axial imbalance above 15 percent of RATED THERMAL POWER. Recalibrate if absolute difference greater than or equal to 3 percent.

(4) -

(Not Used)

(5) -

Each train tested every other month.

(6) -

Neutron detectors may be excluded from CHANNEL CALIBRATION.

(7) -

Below P-10.

(8) -

Below P-6.

(9) -

(Not Used) l (10) -

The CHANNEL OPERABILITY of FUNCTIONAL TEST shall independently verify the the undervoltage and shunt trip circuits for the Manual Reactor Trip Function.

verify the OPERABILITY of The test shall also the Bypass Breaker trip circuit (s).

(11) -

The CHANNEL OPERAPILITY ofFUNCTIONAL the undervoltage and TEST shall independently verify the shunt trip attachments of the Reactor Trip Breakers.

(12) -

Local manual shunt trip prior to service. placing breaker in (13) -

Automatic undervoltage trip.

(14) -

With the reactor trip system breakers closed and the l control rod drive system capable of rod withdrawal.

BEAVER VALLEY - UNIT 1 3/4 3-13 Amendment No.

(Proposed Wording)

TABLE 3.3-3 0

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION g ,

a S

MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. SAFETY INJECTION AND FEEDWATER ISOLATION t

a. Manual Initiation 2 1 _2 1, 2, 3, 4 18

b. Automatic Actuation 2 1 2 1, 2, 3, . 4 13, 36 Logic

c. Containment 3 2 2 1, 2, 3 14 Pressure-High

d. Pressurizer Pressure-Low 3 2 2 1 , 14 g

e. Low Steamline Pressure. 3/ loop 2/ loop - 2/ loop -1 Ily, 14 any loop- any loop -3 ,

-BEAVER VALLEY - UNIT 1 3/4 3-15_. Amendment No.

(Proposed Wording) k

_____.E...

--m.m__u._ ..__._.____.__________-_..____._<m _ _ . - e .-- .. -.J%..-,.,,..e-.<, ,s--,.. . 5--.,... , . < - . . .--.: ,,w_ .- m..mm.___ .-

TABLE 3e3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION @

?

m MINIMUM

TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

4. STEAM LINE ISOLATION

a. Manual 2/ steam line 1/ steam 2/ operating 1, 2, 3 18 line steam line

b. Automatic Actuation 2 1 2 1, 2, 3 13 Logic

c. Containment Pressure 3 2 3 1, 2, 3 14 Intermediate-High-High

d. Low Steamline Pressure 3/ loop 2/ loop any 2/ loop 1 , 14 loop any loop 3 Il

e. High Steam Pressure Rate 3/ loop 2/ loop any 2/ operating 3(2) 14 loop loop BEAVER VALLEY - UNIT 1 3/4 3-18 Amendment No.

(Proposed Wording)

DPR-66 TABLE 3.3-3 (Continued)

TABLE NOTATION (1) Trip function may be bypassed in this MODE below P-11. l (2) Trip function automatically bypassed above P-11, and is bypassed l below P-11 when Safety Injection on low steam pressure is not manually bypassed.

l ACTION STATEMENTS ACTION 13 -

With the number of OPERABLE Channels one less than the i Minimum Number of Channels, be in at least HOT STANDBY l within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the ;

following 30 hours; however, one channel may be l bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per l' Specification 4.3.2.1.1, providec the other channel is operable. l ACTION 14 -

With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP and/or POWER ,

OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l b. The minimum channels OPERABLE requirement is met; )

however, the inoperable channel may be bypassed l for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of l other channels per Specification 4.3.2.1.1.

ACTION 15 -

Not applicable.

ACTION 16 -

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met. One additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per l Specification 4.3.2.1.1.

ACTION 17 -

Not applicable. l ACTION 18 -

With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the l inoperable channal to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

! and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . I l

l BEAVER VALLEY - UNIT 1 3/4 3-20 Amendment No.

, (Proposed Wording) l

DPR-66 TABLE 3.3-3 (Continued)

ACTION STATEMENTS ACTION 33 With the number of OPERABLE Channels one less than the Total Number of Channels, the Emergency Diesel Generator associated with the kV Bus shall be declared j inoperable and the ACTION _ Statements- _ for Specification 3.8.1.1 or Specification 3.8.1.2, as i appropriate, shall apply. .

ACTION 34 With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER ,

OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

b. The Minimum Channels OPERABLE requirement is met; '

however, the inoperable channel may be bypassed l for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of l other channels per Specification 4.3.2.1.1.

l l

l ACTION 36 The block of the automatic actuation logic introduced by a reset of safety injection shall be removed by i resetting (closure) of the reactor trip: breakers '

within one hour of an inadvertent initiation of safety injection providing that all trip input signals have reset due to stable plant conditions. Otherwise, the ,

requirements of ACTION statement 13 shall have been I i met.

ACTION 37 Not applicable. I ACTION 38 With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator' - window (s)

(bistable status lights or computer checks) that'the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

BEAVER VALLEY - UNIT 1 3/4 3-21 Amendment No.

(Proposed Wording)

.. _ _..__...-.m.._ ._ ..... . - . _ - ._-

TABLE 403-2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION y

, SURVEILLANCE REOUIREMENTS :o I

m CHANNEL MODES IN WHICH

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

- FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

1. SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation. N.A. N.A. M(1) .1, 2, 3, 4 b.. Automatic Actuation-Logic N.A. N.A. M(2) 1, 2, 3, 4

c. Containment Pressure-High S R -Q 1, 2, 3

d. Pressurizer Pressure--Low S R' Q- 1, 2, 3

e. Steam'Line Pressure--Low S R Q 1, 2, 3 1

iBEAVER VALLEY - UNIT 1 3/4 3-29 _ .

~

~l Amendment No.-

(Proposed Wording) i

-..__i_i_____ -m______.___.___________m_._

_ _ , . _ _ , .m . , _ _.........m...o . .., .. . , , . . . . . . - - . . . - - . . ...,..,+.,.....-,,.-_......,....L,. -,r . . ..,,..,e... ,,J,._. .-

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION k SURVEILLANCE REQUIREMENTS 7 CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 1.1. SAFETY INJECTION-TRANSFER FROM INJECTION TO THE RECIRCULATION MODE

a. Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4

b. Automatic Actuation N.A. N.A. M(2) 1, 2, 3 Logic Coincident with Safety Injection Signal

c. Refueling Water Storage S R M 1, 2, 3 Tank Level-Low

d. Refueling Water Storage S R M 1, 2, 3 Tank Level - Auto QS Flow Reduction

2. CONTAINMENT SPRAY

a. Manual Initiation N.A. N.A. M(1) 3, 2, 3, 4

b. Automatic Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic

c. Containment Pressure- S R Q 1, 2, 3 l High-High BEAVER VALLEY - UNIT 1 3/4 3-29a Amendment No.

(Proposed Wording)

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION $

SURVEILLANCE REOUIREMENTS 7 CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED

3. CONTAINMENT ISOLATION

a. Phase "A" Isolation

1) Manual N.A. N.A. M(1) 1, 2, 3, 4

2) From Safety Injection N.A. N.A. M(2) 1, 2, 3, 4 Automatic Actuation Logic

b. Phase "B" Isolation

1) Manual N.A. N.A. M(1) 1, 2, 3, 4

2) Automatic Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic

3) Containment Pressure-- S R Q 1, 2, 3 l High-High BEAVER VALLEY - UNIT 1 3/4 3-30 Amendment No.

(Proposed Wording)

.~

TABLE 4.3-2 (Continued) o ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION y SURVEILLANCE REOUIREMENTS 4

m CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

4. STEAM LINE ISOLATION

a. Manual N.A. N.A. M(1) 1, 2, 3

b. Automatic Actuation Logic N.A. N.A. M(2) 1, 2, 3

c. Containment Pressure-- S R Q 1, 2, 3 Intermediate-High-High

d. Steamline Pressure--Low S R Q 1, 2, 3

e. Steamline Pressure Rate-High S R Q 1, 2, 3

5. TURBINE TRIP AND FEEDWATER ISOLATION

a. Steam Generator Water S R Q 1, 2, 3 Level--High-High

6. LOSS OF POWER

a. 4.16kv Emergency Bus N.A. R M 1, 2, 3, 4 Undervoltage (Loss of Voltage)

Trip Feed & Start Diesel

b. 4.16kv and 480v Emergency N.A. R M 1, 2, 3, 4 Bus Undervoltage (Degraded Voltage)

BEAVER VALLEY - UNIT 1 3/4 3-31 Amendment No.

(Proposed Wording)

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

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION e SURVEILLANCE REOUIREMENTS y CHANNEL MODES IN WHICH $

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

7. AUXILIARY FEEDWATER

a. Steam Generator Water S R Q 1, 2, 3 l Level-Low-Low

b. Undervoltage - RCP S R M 1, 2

c. S.I. See 1 above (all SI surveillance requirements) i d. Emergency Bus N.A. R R 1, 2, 3 ,

Undervoltage

e. Trip of Main N.A. N.A. R 1, 2, 3 Feedwater Pumps

8. ESF INTERLOCKS

a. P-4 N.A. N.A. R 1, 2, 3

b. P-11 N.A. R Q 1, 2, 3

c. P-12 N.A. R Q 1, 2, 3 BEAVER VALLEY - UNIT 1 3/4 3-31a Amendment No..

(Proposed Wording)

i l

DPR-66 3/4.3 INSTRUMENTATION BASES 3/4.3.1 AND 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP)

INSTRUMENTATION The OPERABILITY of the protective and ESF instrumentation systems and interlocks ensure that 1) the associated ESF action and/or reactor trip will be initiated when the parameter monitored by each channel or combination thereof exceeds its setpoint, 2) the specified coincidence logic and sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance consistent with maintaining an appropriate level of reliability of the Reactor Protection and Engineered Safety Features instrumentation, and 3) sufficient system functional capability is available for protective and ESF purposes from diverse parameters.

The OPERABILITY of these systems is required to provide the overall reliability, redundancy and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses. The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards. The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP - 10271,

" Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System," and supplements to that report as approved by the NRC and documented in the SER (letter to J. J. Sheppard from Cecil O. Thomas dated February 21, 1985).

Jumpers and lifted leads are not an acceptable method for placing equipment in bypass as documented in the NRC safety evaluation report for this WCAP.

The surveillance requirements for the Menual Trip Function, Reactor Trip Breakers and Reactor Trip Bypast, Breakers are provided to reduce the possibility of an Anticipated Transient Without Scram (ATWS) event by ensuring OPERABILITY of the diverse trip features

(

Reference:

Generic Letter 85-09).

The measurement of response time at the specified frequencies i provides assurance that the protective and ESF action function l associated with each channel is completed within the time limit assumed in the accident analyses. No credit was taken in the analyses for those channels with response times indicated as not applicable.

BEAVER VALLEY - UNIT 1 B 3/4 3-1 Amendment No.

(Proposed Wording) l l

~

l i

DPR-66 ]

INSTRUMENTATION 1 l

BASES 3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP) l JNSTRUMENTATION (Continued)

ESF response times specified in Table 3.3-5 which include. seq 2ential l operation of -the RWST and VCT valves (NOTES # and ##) are based on !

values assumed in the Non-LOCA safety analyses. These analyses take l ;

credit for injection of borated water. Initial borated water is supplied by the BIT, however, injection of borated water from the RWST is assumed not to occur until the VCT charging pump suction valves are closed following opening of the RWST charging pump suction valves. When sequential operation of the RWST and VCT valves is not included in the response times (Note *), the values specified are based on the LOCA analyses. The LOCA analyses.take credit for injection flow regardless of the source. _ Verification of the response times specified in Table 3.3-5 will assure that the assumptions used for the LOCA and Non-LOCA analyses with respect to '

operation of the VCT and RWST valves are valid. ,

Response time may be demonstrated by any series of sequential, j overlapping or total channel test measurements provided that such !

tests demonstrate the total channel response time as-defined. Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test measurements or 2) utilizing replacement sensors with certified response times. ]

'l The Engineered Safety Feature Actuation System interlocks perform '

the following functions:

P-4 Reactor tripped -

Actuates turbine trip, closes main feedwater valves on Tavg below setpoint, prevents the opening of the main feedwater valves which were closed by a safety injection or high steam generator water level signal, allows safety injection block so that components can be reset or tripped. Reactor not tripped -

prevents manual block of safety injection. !

P-11 Above the setpoint P-11 automatically reinstates safety I injection actuation on low pressurizer pressure, automatically blocks steamline . isolation on high steam pressure rate, enables safety injection and steamline isolation on low steamline pressure (with Loop Stop Valves Open), and enables auto actuation of the pressurizer PORV8.

i l

BEAVER VALLEY - UNIT 1 B 3/4 3-la Amendment No.

(Proposed Wording)

i DPR-66 INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP) !

INSTRUMENTATION (Continued)

)

Below the cetpoint P-11 allows the manual block of safety i injection actuation on low pressurizer pressure, allows l manual block of safety injection and steamline isolation on )

low steamline pressure (with Loop Stop Valves Open) and ,

enabling steamline isolation on high steam pressure rate, I automatically disables auto actuation of the pressurizer )

PORVs unless the Reactor Vessel Over Pressure Protection i System is in service. j P-12 Above the setpoint P-12 automatically reinstates an arming signal to the steam dump system. Below the setpoint P-12 '

blocks steam dump and allows manual bypass of the steam dump block to cooldown condenser dump valves.

l l

l i

BEAVER VALLEY - UNIT 1 B 3/4 3-lb Amendment No. l (Proposed Wording)

i i

4 l

- ATTACHMENT C-2 l

j Beaver Valley Power Station, Unit No. 2 l Proposed Technical Specification Change No. 35 i

s Applicable Typed Pages i

1 I

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)

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ATTACHMENT TO LICENSE AMENDMENT NO.

1 FACILITY OPERATING LICENSE NO. NPF-73 DOCKET NO. 50-412 i

Replace the following pages of Appendir A, Technical Specifications, with the enclosed pages as indicated. The revised pages are identified by amendrent number and contain vertical lines indicating ;

the areas of change.

l I

Remove Insert 3/4 3-2 3/4 3-2 3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 '

3/4 3-6 3/4 3-6 3/4 3-7 3/4 3-7 ,

3/4 3-10 3/4 3-10 '

3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-13 3/4 3-13 3/4 3-16 3/4 3-16 3/4 3-18 3/4 3-18 3/4 3-19 3/4 3-19 3/4 3-20 3/4 3-20 3/4 3-21 3/4 3-21 ,

3/4 3-22 3/4 3-22 l 3/4 3-22a j 3/4 3-33 3/4 3-33 !

3/4 3-34 3/4 3-34 3/4 3-35 3/4 3-35 3/4 3-36 3/4 3-36 3/4 3-37 3/4 3-37 B 3/4 3-1 B 3/4 3-1 B 3/4 3-la i

(Proposed Wording)

i TABLE 3.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION y N

MINIMUM b TOTAL NO. CHANNELS CHANNELS APPLICABLE "

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. Manual Reactor Trip 2 1 2 1 , 3 I3) 12 4(3 and S k3)

2. Power Range, Neutron Flux

a. High Setpoint 4 2 3 1, 2 2

b. Low Setpoint 4 2 3 1(1) , 2 2

3. Power Range, Neutron Flux 4 2 3 1, 2 2 High Positive Rate

4. Power Range, Neutron Flux 4 2 3 1, 2 2 High Negative Rate

5. Intermediate Range, Neutron 2 1 2 1(1) 2, 3 I3) 3 Flux 4(3),and 5(3),

6. Source Range, Neutron Flux (Below P-10)

a. Startup 2 1 2 2(2) 3(3) 4 4(3),and 5(3)

b. Shutdown 2 1 2 3, 4, and 5 5

7. Overtemperature AT 3 2 2 1, 2 7

8. Overpower AT 3 2 2 1, 2 7

9. Pressurizer Pressure-Low 3 2 2 1, 2 7 (Above P-7)

10. Pressurizer Pressure-High 3 2 2 1, 2 7 BEAVER VALLEY - UNIT 2 3/4 3-2 Amendment No.

(Proposed Wording)

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION y e

MINIMUM 4 W

TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

19. Safety Injection Input 2 1 2 1, 2 1 from ESF

20. Reactor Coolant Pump 1/ breaker 2 1/ breaker 1 11 Breaker Position Trip per (Above P-7) operating loop

21. Reactor Trip Breakers 2 1 2 1 (3) 40 4 k3p,5}3) 2 1 2 , 39

22. Automatic. Trip' Logic 2 1 2 1 (3) y 2 1 2 4 kp,5 3) 39

23. Reactor' Trip System Interlocks

a. Intermediate Range 2 1 1 2 44 Neutron Flux, P-6

b. Power Range 4 2 3 1- 44 Neutron' Flux, P-8

c. Power Range 4 2 3 1 44 Neutron Flux, P-9

d. Power Range 4 2 3 1, 2 44 Neutron Flux,.P-10

e. Turbine Impulse 2 1 2 1 44 Chamber Pressure, P-13 4

BEAVER VALLEY - UNIT 2 3/4 3-4~ Amendment No.

(Proposed Wording)

i NPF-73 TABLE 3.3-1 (Continued)

TABLE NOTATION (1) Trip function may be manually bypassed in this Mode above P-10.

(2) Trip function may be manually bypassed in this Mode above P-6. j (3) With the reactor trip system breakers in the closed position and I the control rod drive system capable of rod withdrawal.

ACTION STATEMENTS I ACTION 1 - With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the i inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.1.1.1, l

provided the other channel is OPERABLE.

ACTION 2 - With the number of OPERABLE channels one less than the

, Total Number of Channels, STARTUP and/or POWER l OPERATION may proceed provided the following l conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , l

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per specification 4.3.1.1.1, and

c. Either, THERMAL POWER is restricted to less than or equal to 75 percent of RATED THERMAL POWER and the Power Range Neutron Flux setpoint is reduced to less than or equal to 85 percent of RATED THERMAL POWER i within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification !

4.2.4.c.

l ACTION 3 - With the number of channels OPERABLE one less than .

required by the Minimum Channels OPERABLE requirement )

and with the THERMAL POWER level *

a. Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 )

setpoint. j

b. Above P-6 but below 5 percent of RATED THERMAL POWER, l !

restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 5 percent of l RATED THERMAL POWER. I

c. Above 5 percent of RATED THERMAL POWER, POWER l OPERATION may continue.

BEAVER VALLEY - UNIT 2 3/4 3-5 Amendment No.

(Proposed Wording) i

i NPF-73 TABLE 3.3-1 (Continued) !

l l ACTION 4 - With the number of channels OPERABLE one less than )

required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level: '

a. Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 l setpoint and suspend positive reactivity operations.

b. Above P-6, operation may continue.

I ACTION 5 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the Reactor Trip System breakers, suspend all operations involving positive reactivity changes and verify Valve 2CHS-91 is closed and secured in position within the next hour.

ACTION 6 - This Action is not used.

ACTION 7 - With the number of OPERABLE channels (4) one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied;

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

ACTION 8 - With the number of OPERABLE channels one less than the Total Number of Channels and with the THERMAL POWER level above P-9, place the inoperable channel in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; operation may l 1 continue until performance of the next required CHANNEL FUNCTIONAL TEST.

ACTION 9 - This Action is not used.

ACTION 10 - This Action is not used.

l 1

i (4) An OPERABLE hot leg channel consists of: 1) three RTDs per hot I leg, or 2) two RTDs per hot leg with the failed RTD disconnected and the required bias applied.

BEAVER VALLEY - UNIT 2 3/4 3-6 Amendment No.

(Proposed Wording)

NPF-73 TABLE 3.3-1 (Continued)

ACTION 11 - With less than the Minimum Number of Channels -

OPERABLE, operation may continue provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . l .

ACTION 12 - With the number of channels OPERABLE one less than '

required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status '

within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 39 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour. ,

ACTION 40 - a. With one of the diverse trip features (undervoltage or shunt trip attachment) of a reactor trip breaker inoperable, restore the ,

diverse trip feature to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in HOT STANDBY within the 'next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Neither ;

breaker shall be bypassed while one of the diverse trip features is inoperable except for the time required for performing maintenance to ,

restore the breaker to OPERABLE status,

b. With one reactor trip breaker inoperable as a result of something other than an inoperable diverse trip feature, be in at least HOT STANDBY ;

within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up' to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . for surveillance testing per Specification 4.3.1.1.1, provided the I other channel is OPERABLE.

ACTION 44 - With less than the Minimum Number of Channels l l OPERABLE, within 1 hour determine by observation of !

the associated permissive annunciator window (s) that the interlock is in its required state for the existing plant condition, or apply specification 3.0.3.

l l

I BEAVER VALLEY - UNIT 2 3/4 3-7 Amendment No.

(Proposed Wording)

TABLE 4.3-1

~

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS g m

Channel Modes in Which 1 Channel Channel Functional Surveillance "

Functional Unit Check Calibration Test Reauired

1. Manual Reactor Trip N.A. N.A. I, 1 3

2. Power Range, Neutron Flux

a. High Setpoint S D(2) ,

(3) Q 1, 2 l and Q 6)

b. Low Setpoint S R S/U(1) 1(7) , 2

3. Power Range, Neutron Flux, N.A. R Q 1, 2 High Positive Rate

4. Power Range, Neutron Flux, N.A. R Q 1, 2 High Negative Rate S. Intermediate Range, Neutron S R S/U(1) 1 2 3(14),

Flux 4(14j , 5(14)

6. Source Range, Neutron Flux S R S/g)(1) , 2, 3, 4 (Below P-10) QI and 5

7. Overtemperature AT S R Q 1, 2

8. Overpower AT S R Q 1, 2

9. Pressurizer Pressure-Low S R Q 1, 2 (Above P-7)

10. Pressurizer Pressure-High S R Q 1, 2

11. Pressurizer Water Level-High S R Q 1, 2 (Above P-7)

BEAVER VALLEY - UNIT 2 3/4 3-10 Amendment No.

(Proposed Wording)

TABLE 4.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS $

Channel Modes in Which Channel Channel Functional Surveillance Functional Unit Check Calibration Test Recuired

12. Loss of Flow - Single Loop S R Q 1 ,

(Above P-8)

13. Loss of Flow - Two Loop S R Q 1 (Above P-7 and Below P-8)

14. Steam / Generator Water Level- S R Q 1, 2 Low-Low

15. DELETED.

16. Undervoltage-Reactor Coolant N.A. R M 1 Pumps (Above P-7) 1

17. Underfrequency-Reactor N.A. R M 1 Coolant Pumps (Above P-7)

18. Turbine Trip (Above P-9)

A. Emergency Trip. Header N.A. R S/U(1)- 1, 2 Low Pressure i B. Turbine Stop Valve N.A. R S/U(1) 1, 2-Closure

19. Safety Injection Input from N.A. N.A. R 1, 2 ESF

20. Reactor Coolant Pump, Breaker N.A N.A. R N.A Position Trip (Above P-7)

21. Reactor Trip Breaker

~

N.A. N.A. M(5, 11) 1 2 3(14) and S/U(1) 4(14), 5(14I 4

BEAVER VALLEY - UNIT 2 3/4 3-11 Amendment No.

(Proposed Wording)

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

TABLE 4.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS @

m Channel Modes in Which 1 Channel Channel Functional Surveillance W Functional Unit Check Calibration Test Recuired

22. Automatic Trip Logic N.A. N.A. M(5) 1 4(1g) 3(14)5(14)

23. Reactor Trip System Interlocks A. Intermediate Range N.A. R R 1, 2 Neutron Flux, P-6 B. Power Range N.A. R R 1 Neutron Flux, P-8 C. Power Range N.A. R R 1 Neutron Flux, P-9 D. Power. Range N.A. R R 1, 2 Neutron Flux, P-10 E. Turbine Impulse N.A. R R 1 Chamber Pressure, P-13

24. Reactor-Trip Bypass. Breakers. N.A. N.A.

M((12)13), 2 R ,

1(14} 3(14) 4 ,

3(14j BEAVER VALLEY . UNIT 2 3/4 3-12 Amendment No.

(Proposed Wording)

?

NPF-73 TABLE 4.3-1 (Continued)

. TABLE NOTATION (1) -

If not. performed in previous 31 days. l (2) -

Heat balance only, above 15 percent of RATED THERMAL POWER. l (3) -

Compare incore to excore axial imbalance above 15 percent ;

of RATED THERMAL POWER. Recalibrate if absolute difference i greater than or equal to 3 percent.

(4) -

(Not Used).

(5) -

Each train tested every other month on a STAGGERED TEST BASIS.

(6) -

Neutron detectors may be excluded from CHANNEL CALIBRATION. l (7) -

Below P-10. ;

(8) -

Below P-6.

(9) -

(Not Used) l (10) - The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip. circuits for the Manual Reactor Trip Function. The test shall also verify the OPERABILITY of the Bypass Breaker trip circuit (s).

(11) - The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

(12) -

Local manual shunt trip prior to placing breaker in service.

(13) -

Automatic undervoltage trip. l (14) - With the reactor trip . system breakers closed and the l control rod drive syctem capable of rod withdrawal.

/

BEAVER VALLEY - UNIT 2 3/4 3-13 Amendment No.

(Proposed Wording)

'l TABLE 3.3-3 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION @

?

4 MINIMUM W TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION '

1. SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation 2 1 2 1, 2, 3, 4 18

b. Automatic Actuation 2 1 2 1, 2, 3, 4 13, 36 Logic and Actuation Relays

c. Containment. 3 2 2 1, 2, 3 14 Pressure-High

d. Pressurizer 3 2 2 1 2 14 Pressure-Low. 3 k 1) , l t

e. Steamline Pressure-Low 3/ loop 2/ loop 2/ operating 1 2 14 any loop . loop '3

$1), l 1.1. SAFETY INJECTION-TRANSFER FROM INJECTION TO'THE

. RECIRCULATION MODE

a. Automatic Actuation- 2 1 2 1,;2,.3,'4 '18 Logic-Coincident with. Safety Injection Signal-i b. Refueling. Water -4 2 3 1,'2', 3, 4 16 Storage Tank Level-Extreme Low

- BEAVER VALLEY - UNIT 2- 3/4 3-16 Amendment No.

.(Proposed Wording) '

i

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

TABLE 3,3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION $ _

m I

.E MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION'

4. STEAM LINE ISOLATION

a. Manual Initiation

1. Individual 1/ steam line 1/ steam 1/ operating .1, 2, 3 41 line steam line

2. System 2 sets (2 1 set 2 sets 1, 2, 3 18 switches / set)

b. Automatic Actuation 2 1 2 1,~2, 3 13 i- Logic

c. Containment Pressure 3 2 2 1, 2, 3- 14 Intermediate-High-High

d. Steamline Pressure-Low 1 3/ loop 2/ loop any-~2/ operating 1 '14 loop loop 3(1p, l

e. Steamline' Pressure 3/ loop 2/ loop any 2/ operating - 3(2) 14 l Rate--High Negative ' loop loop

5. TURBINE TRIP'&.FEEDWATERL -

ISOLATION

a. Automatic Actuation 2' 1 2 1,-2 42 Logic and; Actuation Relays-

b. Steam Generator 3/ loop 2/ loop in- 2/ loop in 1, 2, 3 14 Water Level--- any-oper- each oper-High-High, P ating loop -- ating1 loop BEAVER VALLEY - UNIT 2 3/4 3 - -

Amendment No.

(Proposed Wording)

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION g

?

w MINIMUM w TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

5. TURBINE TRIP & FEEDWATER ISOLATION (Continued)

c. Safety Injection See Item 1 above for all Safety Injection initiating functions and requirements.

6. LOSS OF POWER

a. 4.16kV Emergency Bus

1. Undervoltage 2/4.16kv Bus 2/4.16kv 2/4.16kv 1, 2, 3, 4 33 (Trip Feed) Bus Bus

2. Undervoltage 1/4.16kV Bus 1/4.16kv 1/4kV Bus 1, 2, 3, 4 33 (Start Diesel) Bus

b. 4.16kv Emergency Bus 2/4.16kv Bus 2/ Bus 2/ Bus 1, 2, 3, 4 34 (Degraded Voltage)

c. 480 Volt Emergency Bus 2/480v Bus 2/ Bus 2/ Bus 1, 2, 3, 4 34 (Degraded Voltage)

7. AUXILIARY FEEDWATER(3) l

a. Automatic Actuation 2 1 2 1, 2, 3 42 Logic and Actuation Relays (3) Manual initiation is included in Specification 3.7.1.2.

BEAVER VALLEY - UNIT 2 3/4 3-19 Amendment No.

(Proposed Wording)

TABLE 3.3-3 (Continued) 2:

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION g

.I4 W

MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

7. AUXILIARY FEEDWATER (Continued)

b. Steam Gen. Water Level--

Low-Low

1. Start. Turbine 3/stm. gen. 2/stm gen. 2/stm. gen. 1, 2, 3 14 Driven Pump any stm.

gen.

2. Start Motor 3/stm. gen. 2/stm gen. 2/stm. gen. 1, 2, 3 14 Driven Pumps any 2 stm.

gen.

c. Undervoltage-RCP (Start (3)-1/ bus 2 2 1, 2 14 Turbine Driven Pump)

d. Safety Injection (Start Motor-Driven Pumps) See 1 above (all SI initiating functions and requirements)

e. Trip of Main Feedwater 1/ pump 2 2 1, 2, 3 18 Pumps (Start Motor Driven Pumps)

8. ENGINEERED SAFETY FEATURE INTERLOCKS

a. Reactor. Trip, 2 l' 2 1, 2, 3 45 P-4

b. Pressurizer Pressure, 3 2 2 1, 2, 3 38 P-11

c. Low-Low T avg, 3 2 2 '1, 2, 3 38 P-12

~

BEAVER VALLEY - UNIT 2 3/4 3-20 Amendment No.

(Proposed Wording)

o NPF-73 TABLE 3.3-3 (Continued)

. TABLE NOTATION (1) Trip function may be bypassed in this MODE below P-11. l (2) Trip function automatically bypassed above P-11, and is bypassed l below P-11 when Safety Injection on low steam pressure is not manually bypassed.

ACTION STATEMENTS ACTION 13 - With the number of OPERABLE channels one less than the Minimum Number of Channels, be in at least HOT STANDBY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 30 hours; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per l Specification 4.3.2.1.1, provided-the other channel is operable.

ACTION 14 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. The minimum channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

ACTION 15 - (This ACTION is not used.)

ACTION 16 - With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is. placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met. One additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1.

ACTION 17 - (This ACTION is not used.) l ACTION 18 - With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the l inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . I BEAVER VALLEY - UNIT 2 3/4 3-21 Amendment No.

(Proposed Wording)

i i

" NPF-73 l TABLE 3.3-3 (Continued)

ACTION STATEMENTS ACTION 33 - With the number of OPERABLE Channels one less than the i Total Number of Channels, the Emergency- Diesel Generator associated with the 4kv- Bus 'shall be declared inoperable and- the ACTION Statements for Specifications 3.8.1.1 or 3.8.1.2, as appropriate, shall apply.

ACTION 34 - With the number of OPERABLE channels'one less than the l Total Number of Channels, STARTUP and/or POWER l OPERATION may proceed. provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed ,

for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of !

other channels per Specification 4.3.2.1.1.

ACTION 36 - The block of the automatic actuation logic introduced by a reset of_ safety injection shall be removed by resetting (closure) of the reactor trip breakers within one hour of an inadvertent initiation of safety injection providing that all trip input signals have reset due to stable plant conditions. Otherwise, the requirements of ACTION Statement 13 shall have been met.

l ,

(This ACTION is not used)

ACTION 37 -

ACTION 38 - With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window (s)

(bistable status lights or computer checks) that the i interlock is in its required state for~.the existing plant condition, or apply Specification 3.0.3.

ACTION 41 - With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months cn- declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

BEAVER VALLEY - UNIT 2 3/4 3-22 Amendment No. :

(Proposed Wording)

.* HPF-73 TABLE 3.3-3 (Continued)

ACTION STATEMENTS ACTION 42 - With the number of OPERABLE Channels one less than the minimum Channels OPERABLE requirement, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for i surveillance testing per Specification 4.3.2.1.1 provided the other Channel is OPERABLE.

I ACTION 45 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable l channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at

least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT l SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l l

1 BEAVER VALLEY - UNIT 2 3/4 3-22a Amendment No.

(Proposed Wording)

TABLE 4.3-2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION M SURVEILLANCE REQUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

1. SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation N.A. N.A. 'M(1) 1, 2, 3, 4

b. Automatic-Actuation Logic N.A. N.A. M(2)

. 1, 2, 3, 4 and Actuation ~ Relays

c. Containment Pressure-High S R Q 1, 2, 3

d. Pressurizer Pressure--Low S R Q 1, 2, 3

e. Steam Line Pressure--Low S R Q 1, 2, 3 1.1. SAFETY INJECTION-TRANSFER FROM INJECTION TO THE' RECIRCULATION MODE

a. Automatic Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic, Coincident with Safety Injection Signal

b. . Refueling Water Storage S R M 1, 2, 3, 4 Tank Level-Extreme Low BEAVER VALLEY.- UNIT 2 3/4 3-33 Amendment No.

> (Proposed Wording)

i TABLE 4.3-2 (Continued) l ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION $

SURVEILLANCE REOUIREMENTS m t

u CHANNEL MODES IN WHICH ;

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED t

2. CONTAINMENT SPRAY 4

a. Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4 '

b. Automatic Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic, and Actuation Relays

c. Containment Pressure- S R Q 1, 2, 3 l Migh-High i - 3. CONTAINMENT ISOLATION

a. Phase "A" Isolation

1. - Manual Initiation N.A. N.A. M(1) 1, 2, 3, 4 i

2. ' Automatic Actuation .N.A. N.A. M(2) 1, 2, 3, 4 Logic'and Actuation Relays

3. Safety Injection See Functional Unit 1 above for all Safety Injection Surveillance Requirements.

b. Phase "B" Isolation

1. Manual Initiation N . A '. N.A. M(1) 1, 2, 3, 4 .

2. Automatic' Actuation N.A. N.A. M(2) 1, 2, 3, 4 Logic and Actuation Relays

3. Containment. Pressure-- S R Q 1, 2, 3, 4 I High-High BEAVER VALLEY - UNIT 12 3/4 3-34 Amendment No.

(Proposed Wording) 1

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

TABLE 4.3-2 (Continued) z ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION @

SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

4. STEAM LINE ISOLATION

a. Manual Initiation

1. Individual N.A. N.A. M(1) 1, 2, 3

2. System N.A. N.A. M(1) 1, 2, 3

b. Automatic Actuation Logic N.A. N.A. M(2) 1, 2, 3 and Actuation Relays

c. Containment Pressure-- S R Q 1, 2, 3 Intermediate-High-High

d. Steamline Pressure--Low S R Q 1, 2, 3

e. Steamline Pressure Rate-High S R Q 1, 2, 3 Negative

5. TURBINE TRIP AND FEEDWATER ISOLATION

a. Automatic Actuation Logic N.A. N.A. M(2) 1, 2, 3 and Actuation Relays

b. Steam Generator Water S R Q 1, 2, 3 l Level--High-High, P-14

c. Safety Injection See Functional Unit 1 above for all Safety Injection Surveillance Requirements.

BEAVER VALLEY - UNIT 2 3/4 3-35 Amendment No.

(Proposed Wording)

TABLE 4.3-2 (Continued) 2:

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION $

SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

6. LOSS OF POWER

a. 4.16kv Emergency Bus

1. Undervoltage (Trip Feed) N.A R M 1, 2, 3, 4 l

2. Undervoltage (Start Diesel) N.A R M 1, 2, 3, 4

b. 4.16kv Emergency N.A. R M 1, 2, 3, 4 Bus (Degraded Voltage)

c. 480v Emergency Bus N.A. R M 1, 2, 3, 4 (Degraded Voltage)

7. AUXILIARY FEEDWATER(4) l

a. Automatic Actuation Logic N.A N.A. M(2) 1, 2, 3 and Actuation Relays

b. Steam Generator Water Level-Low-Low

1. Start Turbine Driven S R Q 1, 2, 3 l Pump

2. Start Motor Driven S R Q 1, 2, 3 l Pumps 1

(4) Manual initiation is included in Specification 4.7.1.2. l BEAVER VALLEY - UNIT 2 3/4 3-36 Amendment No.

(Proposed Wording)

- _ _ ~ _ _ _ _ - - - - - _ - _ _ _ _ - - _ _ _ _ - _ _ _ - _ _ _ - _ _ - _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _

TABLE 4.3-2 (Continued) 2:

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION $

SURVEILLANCE REOUIREMENTS 4

w CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

7. AUXILIARY FEEDWATER (continued)

c. Undervoltage - RCP (Start S R M 1, 2 Turbine-Driven Pump)

d. Safety Injection (Start See 1 above (all SI surveillance requirements)

Motor-Driven Pumps)

e. Trip of Main N.A. N.A. R 1, 2, 3 Feedwater Pumps (Start Motor-Driven Pumps)

8. ENGINEERED SAFETY FEATURE INTERLOCKS

a. Reactor Trip, P-4 N.A. N.A. R(3) 1, 2, 3

b. Pressurizer Pressure, P-11 N.A. R Q 1, 2, 3

c. Low-Low T avg, P-12 N.A. R Q 1, 2, 3 BEAVER VALLEY - UNIT 2 3/4 3-37 Amendment No.

(Proposed Wording)

i NPF-73 3/4.3 INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION

! The OPERABILITY of the R3 actor Protection System and Engineered Safety Feature Actuation System Instrumentation and interlocks ensure

, that 1) the associated action and/or reactor trip will be initiated l

when the parameter monitored by each channel or combination thereof reaches its setpoint, 2) the specified coincidence logic and sufficient redundancy is maintained to permit a channel to be out of l service for testing or maintenance consistent with maintaining an appropriate level of reliability of the Reactor Protection and Engineered Safety Features instrumentation, and 3) sufficient system functional capability is available from diverse parameters.

The OPERABILITY of these systems is required to provide the overall reliability, redundancy, and diversity assumed available in i

the facility design for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses. The surveillance requirements specified for these systems 1 ensure that the overall system functional capability is maintained !

comparable to the original design standards. The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP - 10271,

" Evaluation of Surveillance Frequencies and Out of Service Times for i the Reactor Protection Instrumentation System," and supplements to that report as approved by the NRC and documented in the SER (letter to J. J. Sheppard from Cecil O. Thomas dated February 21, 1985).

Jumpers and lifted leads are not an acceptable method for placing equipment in bypass as documented in the NRC safety evaluation report for this WCAP.

The Engineered Safety Feature Actuation System Instrumentation Trip Setpoints specified in Table 3.3-4 are the nominal values at which the bistables are set for each functional unit. A setpoint is considered to be adjusted consistent with the nominal value when the "as measured" setpoint is within the band allowed for calibration accuracy.

To accommodate the instrument drift assumed to occur between operational tests and the accuracy to which setpoints can be measured and calibrated, Allowable Values for the setpoints have been specified in Table 3.3-4. Operation with setpoints less conservative than the Trip Setpoint but within the Allowable Value is acceptable BEAVER VALLEY - UNIT 2 B 3/4 3-1 Amendment No.

(Proposed Wording)

NPF-73 3/4.3 INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION (Continued) since an allowance has been made in the safety analysis to -

accommodate this error. An optional provision has been included for determining the OPERABILITY of a channel when its trip setpoint is found to exceed the Allowable Value. The methodology of this option utilizes the "as measured" deviation from the specified calibration point for rack and sensor components in conjunction with a statistical combination of the other uncertainties of the instrumentation to measure the process variable and the uncertainties in calibrating the instrumentation. In Equation 2.2-1, Z+R+S$

TA, the interactive effects of the errors in the rack and the- sensor, and the "as measured" values of the errors are considered. Z, as specified in Table 3.3-4, in percent span, is the statistical summation of errors assumed in the analysis excluding those associated with the sensor and rack drift and the accuracy of their measurement. TA or Total Allowance is the difference, in percent span, between the trip setpoint and the value used in the analysis for the actuation. R or Rack Error is the "as measured" deviation, in percent span, for the affected channel from the specified trip setpoint. S or Sensor Drift is either the "as measured" deviation of the sensor from its calibration point or the value specified in Table 3.3-4, in percent span, from the analysis assumptions. Use of Equation 2.2-1 allows for a sensor drift factor, an increased rack drift factor, and provides a threshold value for REPORTABLE EVENTS.

BEAVER VALLEY - UNIT 2 B 3/4 3-la Amendment No. l (Proposed Wording)

I .- . ATTACHMENT D l

Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES l

l BV-1 Chances BV-2 Chances Table 3.3-1 Table 3.3-1 Table 4.3-1 Table 4.3-1 Table 3.3-3 Table 3.3-3 Table 4.3-2 Table 4.3-2 l

I i

l l

1 i

D-1 j

- .. ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES BV-1 CHANGES Table 3.3-1 Editorial Chances and Functional Unit Revisions to Reflect WCAP-10271 Supplement 1

1,5,6.a,21,22 Editorial, change

symbol to (3).

7,8 Delete two loop operating requirements since this is not a licensed operating condition.

-

Note Editorial, change

symbol to (3).

- Note Delete this note since it is only applicable for two loop operating requirements which are deleted above.

Actions 1,2,7,40 Incorporated correct reference to Specification 4.3.1.1.1.

Action 1 Changed to reflect Action 14.

Action 2 Changed to reflect Action 2.

Action 3 Editorial, replaced symbols with words.

Action 7 Changed to reflect Action 6.

Note Editorial, change

symbol to (4).

Action 8 Changed the time required to place a channel in trip from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in accordance with the guidance provided in WCAP-10271 Supplement 1 where the allowable outage times are increased.

Action 9 Delete this action since the two loop operating requirements have been deleted.

Action 11 Changed the time required to place a channel in trip from i hour to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in accordance with the guidance provided in WCAP-10271 Supplement 1 where the allowable outage times are increased.

Action 40 Editorial, add "the next" for consistency with the BV-2 action wording.

D-2

- ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES v-BV-1 CHANGES (Continued)

Table 4.3-1 Editorial Chances and j Functional Unit Revisions to Reflect WCAP-10271 Suoolement 1 5,21,22,24 Editorial, change

symbol to (14).

l 2.a,3,4,6,7,8,9,10 Changed the Channel Functional Test frequency 11,12,14,15 from M to Q.

5 Deleted monthly Channel Functional Test.

13 This item is not listed in the NUREG 0452 STS, however, the frequency is changed to reflect Functional Unit 12.

23 Changed the Channel Functional Test frequency from M to R in accordance with NRC letter dated July 24, 1985 to L. D. Butterfield.

Note Editorial, change

symbol to (14).

Note (1) Changed the frequency from 7 to 31 days.

Notes (2) and (3) Editorial, replaced symbols with words.

Note (9) Deleted since this note no longer applies to any function.

Bases 3/4.3.1 and 3/4.3.2 Incorporated the revisions recommended in WCAP-10271 along with an additional sentence to provide the NRC position concerning installed bypass capability.

D-3

1 i

i

- . ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 l DESCRIPTION OF CHANGES !

j BV-1 CHANGES !

(Continued) l 1

Table 3.3-3 Editorial Chances and Revisions to l Functional Unit Reflect WCAP-10271 Sucolement 2. Revision 1 l 1.d,1.e,4.d Editorial, change # symbol to (1). j 4.e Editorial, change ## symbol to (2).

1.e and 4.d Delete two loop operating requirements since this is not a licensed operating condition and correct the wording to reflect the BV-2 j format. ,

4.e Replace Action 37 applied to this item with Action 14. i 5.a and 5.b Editorial, renumber item 5.a " Steam Generator Water Level--High-High, P-14" to item 5.b and l renumber item 5.b " Automatic Actuation Logic and Actuation Relays" to item 5.a for I consistency with the other ESF tables. 1 i

Note Editorial, change # symbol to (1). )

1. Note Editorial, change ## symbol to (2), j

1. 1. Note Delete this note since it is only applicable for two loop operating requirements which are deleted above. j Action 13 Changed to reflect Action 14.

Actions 14,16 Incorporated correct reference to Specification 4.3.2.1.1.

Action 14 Changed to reflect Action 20.

l Action 15 Delete this action since this only applied to l two loop operating requirements which have l been deleted.

l l

l D-4

- ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES BV-1 CHANGES (Continued)

Table 3.3-3 Editorial Chances and Revisions to.

Functional Unit Reflect WCAP-10271 Supplement 2. Revision 1 Action 16 Changed to reflect Action 17. ,

Action 17 Delete this action and identif'j as "Not Applicable" since this action doo,s not apply to any function.

Action 18 Changed to reflect Action 19.

Action 34 Changed to reflect Action 20, but maintained the NUREG-0452 STS 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months allowable outage time since the NRC review did not f.nclude the functional unit this action applies to, Loss of Power.

Action 36 Editorial, change " action" to " ACTION" to correct an error.

Action 37 Delete this action and apply Action 14 to Item ;

4.e.

l l

D-5

di j .

ATTACHMENT D l Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 ,

DESCRIPTION OF CHANGES

]

i l

J BV-1 CHANGES !

(Continued) ]

l 1 Table 4.3-2 Editorial Channes and Revisions to l Functional Unit Channel Functional Test Frecuency to Reflect WCAP-10271 Supolement 2. Revision 1

( i

{ 1.c,1.d,2.c,3.b.3, M to Q.

i 4.c,5.a,7.a,8.b,8.c j 1.e,4.d,4.e M t) Q in accordance with April 1990 SSER.

d 1

1 4

1 1

i i

i 1

f i

4

D-6 1

ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 l Proposed Technical Specification Change No. 173/35 l DESCRIPTION OF CHANGES BV-2 Chances j Table 3.3-1 Editorial Chances and l Functional Unit Revisions to Reflect WCAP-10271 Suoolement 1 I l

1,5,6.a,21,22 Editorial, change

note to (3). I

Note Editorial, change

note to (3).

Action 1 Changed to reflect Action 14. )

i Actions 1,2,7,40 Incorporated correct reference to Specification 4.3.1.1.1. i Action 2 Changed to reflect Action 2.

Action 3 Editorial, replaced symbols with words.

Action 4 Editorial, added word "the."

Action 7 Changed to reflect Action 6.

l

Note Editorial, change

note to (4). j i

Action 8 Changed the time required to place a channel I in trip from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in accordance with the guidance provided in the WCAP where the allowable outage times are increased.

Action 11 Changed the time required to place a channel in trip from i hour to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in accordance l with the guidance provided in the WCAP where the allowable outage times are increased.

Action 44 Editorial, changed " channels" to " Channels" to correct an error.

D-7

ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES BV-2 CHANGES (Continued)

Table 4.3-1 Editorial Chances and Functional Unit Revisions to Reflect WCAP-10271 Sucolement 1 1,5,21,22,24 Editorial, change

symbol to (14).

2.a,3,4,6,7,8,9,10 Changed the Channel Functional Test frequency 11,12,14,15 from M to Q.

5 Deleted monthly Channel Functional Test.

13 Changed Channel Functional Test frequency from "See 12 above" to Q. This item is not listed in the NUREG 0452 STS, however, the frequency is changed to reflect Functional Unit 12.

23 Changed the Channel Functional Test frequency from M to R in accordance with NRC letter dated July 24, 1985 to L. D. Butterfield.

Note Editorial, change

note to (14).

Note (1) Changed the frequency from 7 to 31 days.

Notes (2) and (3) Editorial, replaced symbols with words.

Note (9) Deleted since this note no longer applies to any function.

Note (13) Delete reference to Cycle 1, this is no longer required.

Bases 3/4.3.1 and 3/4.3.2 Incorporated the revisions recommended in WCAP-10271 along with an additional sentence to provide the NRC position concerning installed bypass capability.

I 1

1 1

D-8 j

/

ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES BV-2 CHANGES (Continued)

Table 3.3-3 Editorial Chances and Revisions to Functional Unit Beflect WCAP-10271 Sucolement 2. Revision 1 1.d,1.e,4.d Editorial, change # note to (1).

4.e Editorial, change ## note to (2).

7 Editorial, change

note to (3).

4.e Replace Action 34 applied to this item with Action 14.

Note Editorial, change # note to (1).

1. Note Editorial, change ## note to (2).

Action 13 Changed to reflect Action 14.

Actions 14,16 Incorporated correct reference to Specification 4.3.2.1.1.

Action 14 Changed to reflect Action 20.

Action 16 Changed to reflect Action 17.

)

Action 17 Delete this action and identify as (This ,

Action is not used) since this action does not I apply to any function.

Action 18 Changed to reflect Action 19.

Action 34 Changed to reflect Action 20, but maintained the NUREG-0452 STS 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months allowable outage time since the NRC review did not include the functional unit this action applies to, Loss of Power.

Action 42 Changed the time a channel may be bypassed for surveillance testing from 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months in accordance with the guidance provided in the WCAP where the allowable surveillance outage times are increased.

D-9

., ATTACHMENT D Beaver Valley Power Station, Unit Nos. 1 and 2 Proposed Technical Specification Change No. 173/35 DESCRIPTION OF CHANGES :

l 4

BV-2 CHANGES i (Continued) l

)

Table 4.3-2 Editorial Chances and Revisions to Functional Unit Channel Functional Test Freauency to Reflect WCAP-10271 Supolement 2. Revision 1 I 1.c,1.d,2.c,3.b.3, M to Q.

4.c,5.b,7.b.1, l 7.b.2,8.b,8.c 1.e,4.d,4.e M to Q in accordance with April 1990 SSER.

6.a.1 Move the frequencies and modes down to the correct line.

7 Editorial, change

note to (4).

+

t I

D-10

ML20059D642

Text

Reference:

Reference:

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