Text

Proposed Tech Specs Revising 840313 Submittal (Proposed Change Request 86) to Address NRC Recommendations Re Reactor Trip & ESF Instrumentation Tables.Justification Encl
	ML20093E753
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Site:	Beaver Valley
Issue date:	07/03/1984
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	NUDOCS 8407180098
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a TABLE 2.2-1 (Continued) f REACIOR TRIP SYSTEM INSTRINENPATIOi 'IRIP SETPOINPS n

o FUNCPIONPL UNIT TRIP SEITOINP ALIDWABLE VAIDES D

5;

[

13. Steam Generator Water 2 12% of narrow range instrument 2 11% of narrow range instrument Icvel-Iow-Iow span-each steam generator span-each steam generator z

U

14. Steam /Feedwater Flow f 40% of full steam flow at f 42.5% of full steam flow at Mismatch and Iow Steam RATED 'I1IERMAL POWER coincident RATED 'I1IERMAL POWER coincident Generator Water IcVel with steam generator water level with steam generator water level 2,25% of narrow range instru-2 24% of narrow range instru-ment span-each steam generator ment span-each steam generator o

E

15. Undervoltage-Beactor A 2750 volts-each bus p 2725 volts-each bus y

Coolant Punps

~

m {

16. Underfrequency-Reactor 2 57.5 IIz - each bus 2 57.4 IIz - each bus g

Coolant Pumps o

E

17. Turbine Trip A.

Auto stop oil pressure 45 psig i 5 psig B.

Turbine Stop Valve A 1% open 21% open

18. Safety Injection Input Not Applicable Not Applicable from ESP

19. Reactor Coolant Punp Not Applicable Not Applicable Breaker Position Trip

20. Pcactor Trip System Interlocks (Based on ascending power)

-0

-11 A.

Intermediate Range 21 x 10 Anps y 6 x 10 Anps Neutron Flux, P-6 8407180098 840703 PDR ADOCK 05000334 P

pyg

E 4

m, 1

. TABLE 2.2-1 (Continued)-

m b

' REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINT m

c:(

20. (Continued)

{

Q FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES E

M B. Power Range-Neutron Flux, P-8 130% RATED THERMAL POWER 6 31% RATED THERMAL POWER r.

C. Power Range Neutron Flux,'P-9 649% RATED THERMAL POWER 6 51% RATED THERMAL POWER E

D. Power Range e

Neutron Flux, P-10

> 9% RATED THERMAL POWER e 12% RATED THERMAL POWER (Input to P-7) cE E. Turbine Impulse y

Chamber Pressure, P-13 5 66 PSIG 672 PSIG g

(Input to P-7) o

5 LIMITING SAFETY SYSTEM SEITINGS f

BASES Safety Injection Input from ESF If ' a reactor. trip has not already been generated by the reactor protective instrumentation, the ESF autmatic actuation logic channels will initiate a reactor trip upon any signal which initiates a safety injection.

'Ihis trip is provided to protect the core in the event of a II)CA. 'Ihe ESF instrumentation channels which initiate a safety injection signal are shown

.in Table 3.3-3.

Reactor Coolant Punp Breaker Position Trip

'Ihe Reactor Coolant Punp Breaker Position Trips are anticipatory trips which _ provide reactor core protection against DNB resulting frm the opening of two or more pump breakers above P-7.

These trips are blocked below P-7.

'Ihe open/close position trips assure a reactor trip signal is generated before the low flow trip set point is reached.

No credit was taken in the accident analyses for operation of these trips.

Their functional capability at the open/close position settings is required to enhance the overall reliability of the Peactor Protx: tion System.

Reactor Trip System Interlocks

- The Reactor Trip System Interlocks perform tM rollowing ftmetions:

P-6 Above the 'setpoint P-6 allcws the manuel bicck of. the Scurce Range reactor trip and de-energizing of the high voltage to tba detectors.

Below the setpoir.t Source Range level trips are autmatically reactivated and high voltage restored.

P-7. Above the setpoint P-7 autmatically enables reactor trips on low flow or coolant pump ' breaker open in more than one primary coolant

locp, reactor coolant pump bus undervoltage and underfrequency, pressurizer low pressure and pressurizer high level.

Below the setpoint the above listed ~ trips. are autmatically blocked.

P-8 Above the 'setpoint P-8 autcrnatically enables reactor trip on low

~ flow in one or nere primary coolant loops.

Below the setpoint P-8 automatically blocks the above listed trip.

P-9 Above the setpoint P-9 autmatically enables a reactor trip on

' turbine trip.

Below the setpoint P-9 autcreatically blocks a reactor trip on turbine trip.

.P-10 Above the setpoint P-10 allows the n'anual block of the Inta-diate Range reactor trip and the low setpoint Power Range reactor trip; and autmatically blocks the Source Range reactor trip and de-energizes the Source Pange high voltage power. Below the setpoint the Intermediate Range reactor trip and the low setpoint Power Range reactor trip are autmatically reactivated.

- - - ~

Provides input to P-7.

l I

P-13 Provides input to P-7.

l i

L BEAVER VAILEY - UNIT 1 B 2-8 i

PROPOSED UOFDING I

~..

TABIE 3.3-1 en9' RF1CIOR 'IRIP SYSTEM INSTIGENTATION~

i E

MINIM M

'IUPAL NO.

CHANNEIS OIANNELS APPLICABLE I

E-FUNCTIONAL UNIT OF OIANNEIS

'ID TRIP OPERABIE MODES ACTICN i

l'.

Manual Reactor Trip 2

1 2

1, 2, 3*,4*,

12 0

and 5*

4 s

2.

Power Range, Neutron Flux l

a.

liigh Setpoint 4

2 3

1, 2 2

b.

Iow Setpoint 4-2 3

1(1),2 2

I m

3.

Power Range, Neutron Flux 4

2 3

1, 2 2

Ilich Positive Rate i

3

$M 4.

Power Range, Neutron Flux, 4

2 3

1, 2 2

i Ifigh Negative Rate

$Y i

5.

Intennodiate Range, Neutron Flux 2

1 2

1(1), 2, 3*,

3 G

4*, and 5*

a 6.

Source Range, Neutron Flux-(Below P-10) 2 ( I,

3*, 4 *,

4 A.

Startup 2

1 2

and 5*

i B.

Shutdown 2

0 1

3, 4 and 5 5

7.

OvertemperatureAT

'Ihree loop Operation 3

2 2

1, 2 2

'nx) Icop Operation 3

1**

2 1, 2 9

8.

OverpowerAT

'Ihree loop Operation 3

2 2

1, 2 2

Two Icop Operation 3

1**

2 1, 2 9

9.

Pressurizer Pressure-Iow 3

2 2

1, 2 7

(Above P-7) 4 m

.v

1 TABIE 3.3-1 (Continued)

RP1CIOR TRIP SYS'ITM INSTRLNENPATION

<~

E MINIM M

'lUPAL NO.

GIANNELS QIAlsNELS APPLICABIE h

FUNCTIONAL UNIT OF GIANNELS

'IO TRIP OPERABIE KDES ACPICN a

10. Pressurizer Pressure-Iligh 3

2 2

_1, 2

7 E

U 11.

Pressurizer Water IcVel-Iligh 3

2 2-1, 2 7.

(Above P-7) 12.

Ioss of Flow - Single Icop 3/ loop 2/ loop in 2/ loop in 1

7 i

(Above P-8) any oper-each oper-g ating loop ating loop

)

o o

13.

Ioss of Flow

'Iko Icops 3/ loop 2/ loop in 2/ loop 1

7 h{

(Above P-7 and below P-8) t1x) oper-each oper-ating loops ating loop o:$"

14.

Steam Generator Water 3/ loop 2/ loop 2/ loop 1, 2 7

z IcVel-Low-Iow (Icop Stop Valves Open) 15.

Steam /Feedwater Flow 2/ loop-level 1/ loop-level 1/ loop-level 1, 2 7

Mismatch and Iow Steam and coincident and Generator Water Ievel 2/ loop-flow with 2/ loop-flow mismatch 1/ loop-flow mismatch or mismatch in 2/ loop-level same loop and 1/ loop-flow mismatch 16.

Undervoltage-Reactor Coolant 3-1/ bus 2

2 1

7 Pumps (Above P-7) l 17.

Underfrequency-Reactor Coolant 3-1/ bus 2

2 1

7 Punps (Above P-7) l

TABLE 3.3-1 (Continued)

REACIOR 'IRIP SYSITM INSTRLEENTATION y

MINIM M

'IUPAL NO.

OIAbNE[S OIANNELS APPLICABLE MICTIONAL UNIT OF OIANNEIS TO TRIP OPERABLE MODES JCTICN

<>c

18. Turbine Trip (Above P-9) l A.

Auto Stop Oil Pressure 3

2 2

1 7

4 B.

Turbine Stop Valve Closure 4

4 4

1' 8

e c:

19.

Safety Injection Input frcxn ESF 2

1 2

1, 2 1

a 20.

Reactor Coolant Ptmp Breaker r

Position Trip l

(Above P-7) 1/ breaker-2 1/ breaker 1

11

o per oper-S_

ating loop o

$U 21.

Reactor Trip Breakers 2

1 2

1, 2, 3*,

1 e e.

4*, and 5*

cu

$5

22. Autcxnatic Trip Iogic 2

1 2

1, 2, 3*,

1 0

4*, and 5*

z 23.

Reactor Trip System Interlocks A.

Intennediate 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 Inpulse 2

1 1

1 12 Chamber Pressure, P-13

.c 9

TABLE 3.3-1 (Continued)

TABLE NOTATIN With the reactor trip system breakers in the closed position and the control rod drive system capable of rod withdrawal.

The channel (s) associated with the protective functions derived frm the out.of service Peactor Coolant Icop shall be placed in the tripped condition.

(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.

AcrION STATDDTIS ACTICN 1 '-

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirements, be in hor STAlOBY within G hours.

ACTION 2 -

With the nurrber of OPERABLE channels one less than the Total Nunter of Channels and with the THERMAL PNER level:

a.

Iess than or equal to 5% of RATED THERMAL POWER, place the inoperable channel in the tripped cordition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and restore the incperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after increasing THERBE POH above 5% of RATED U!ERMAL POWER; otherwise reduce thermal power to less than 5% RATED THERMAL POWER within tha following 6 Fours, b.

Above 5% of RATED THEPMAL PG E, operation may continue provided all of.the following conditions are satisfied:

1.

The inoperable channel is placed in the tripped condition within 1 Four.

2.

The Minimum Channels OPERABLE requirement is met; however, one additional 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 Specif-cation 4.3.1.1, 3.

Either, THERFE PGG is restricted to675% of PATED THER@L and the Power Range, Neutron Flux trip set-point is reduced tof 85% of PATED THER&L POE within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT PGG TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACIICN 3 -

With the nirber of channels OPEPABLE one less than required by the Minimum Omnnels OPERABLE requirement and with the THERMAL PO E level:

BEAVER VALLEY - UNTr 1 3/4 3-5 PROPOSED IORDING

.-w.. - -.

.v 4

m-w

. ~ ~..

.~.

TABLE 3.3-1 (continued) 7CTION 9 With a channel associated with an operating locp inoperable, restore the inoperable channel to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in hor STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel associated with an operating loop 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.

ACTION 10 Not applicable.

ACTION 11 With less than the Minimum Number of Channels OPERABLE, operation may continue provided the iroperable charmel is placed in the tripped condition within 1 icur.

ICTION 12 With the nurter 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 bours and/or open the reactor trip breakers.

h 3EAVER VALLEY - UNIT 1 3/4 3-7/8 PROPOSED TORDING 4

)

q..

i I

~

TABLE 4.3-1 REAC'IOR TRIP SYSIB4 INSTIGENTATION SURVEIIJANCE REQUIRENENTS l

OIA14EL PODES IN MIIGI' OIN&EL OIAt@EL FUNCTIONAL SURVEILIANCE EUNCTICNAL UNIT OlBCK CALIBRATION TEST REQUIRED 1.

Manual Ibactor Trip N.A.

N.A.

S/U(1)

N.A.

r E

2.

Power Range, Neutron Flux i

a.

liigh Setpoint S

D(2), M(3)

M 1, 2,

i c=

and Q(6)

G b.

Iow Setpoint S

N.A.

S/U(1) 2 O

s l

3w 3.

Power Range, Neutron Flux, N.A.

R M

1, 2 y2 fligh Positive Rate o

cY 4.

Power Range, Neutron Flux, N.A.

R M

1, 2

[

liigh Negative Rate n

E 5.

Intenrediate Range, S

N.A.

S/U(1), M(7) 1, 2, 3*,

l 0

Neutron Flux 4 *, 5*

6.

Source Range, Neutron Flux N.A.

N.A.

S/U(1), M(8) 2, 3*, 4*

(Below P-10) and 5*

7.

Overtsperature T S

R M

1, 2 8.

Overpower T S

R M

1, 2 9.

Pressurizer Pressure-Iow S

R M

1, 2 (Above P-7) l 10.

Pressurizer Pressure-liigh S

R M

1, 2 11.

Pressurizer Water Invel-Iligh S

. R M

1,_2 (Above P-7) l 12.

Ioss of Flow - Single Icop S

R M

1 I

h

T TABIE 4.3-1 (Continued)

REACIOR TRIP SYSTEM INS'IMMNTATIO4 SURVEILIANCE REQUIRD4ENTS OIAtNEL MJDES IN MIIOi aiAnnEn ainnnEn menOaL SuRvErumcE rn EUNCTIORL UNIT OIECK CALIBRATION TEST REQUIRED w

y 13.

Ioss of Flow

'Ibo Icops S

R' N.A.

1' e

14.

Steam / Generator Water IcVel-S R

M 1, 2 d

Iow-Iow I

15.

Steam Feedwater Flow Mismatch and S R

M 1, 2 c

Iow Steam Generator Water IcVel a

16.

Undervoltage - Peactor Coolant N.A.

R M

1

~

Punps (Above P-7) l 17.

Underfrequency - Reactor Coolant N.A.

R M

1 3m Punps (Above P-7) l vm E

18.

'Ibrbine Trip (Above P-9) c.

o-A.

Auto Stop Oil Pressure N.A.

N.A.

S/U(1) 1, 2 mu 5

B.

Turbine Stop Valve Closure N.A.

N.A.

S/U(1) 1, 2 v.

19.

Safety Injection Input frcm ESF N.A.

N.A.

M(4) 1, 2 20.

Reactor Coolant Punp Breaker N.A.

N.A.

R N.A.

Position Trip 21.

Reactor Trip Breaker N.A.

N.A.

M(5) and S/U(1) 1, 2, 5*

22.

Automatic Trip Iogic N.A.

N.A.

M(5) 1, 2, 5*

23.

Reactor Trip System Interlocks A.

P-6 N.A.

N.A.

M(9) 1, 2 B.

P-8 N.A.

N.A.

M(9) 1 C.

P-9 N.A.

N.A.

M(9) 1 D.

P-10 N.A.

N.A.

M(9)

,1 E.

P-13 N.A.

R M(9) 1

P TABLE 4.3-1 (Continued)

- NCTTATICN With the reactor trip system brealers closed and the control

. rod drive system capable of rod withdratral.

(1)

If not performed in previous 7 days.

(2)

Heat balance only, above 15% of PATE THERRL POWER.

-(3)

Cartpare incore to excore axial imbalance above 15% of PATE THER%L POWER.

Becalibrate if absolute difference 2 3 percent.

(4)

Manual ESF functional input check every 18 months.

(5)

Each train tested every other nonth.

(6)

Neutron detectors may be excluded frm CHENEL CALIBRATION.

(7)

Below P-10 (8)

Below P-6.

(9)

Recuired cnly when below Interlock Trip Setpoint.

- BFAVER VALLEY - UNIT 1 3/4 3-13 PROECSED NORDING

TAB E 3.3-3 ENGINIEED SAITlY FFA'IURE ACIUATIN SYS'ITM INS'IMMNPATIN ca 9

<:5 MINIM N I

'IOPAL NO.

CHAME[S GAMEIS APPLICABLE FUNCTIONAL UNIT OF GAMETE

'IO TRIP -

OPERABLE KDES ACPION 5<

1.

SAFEIY INJDCPION AND E

FEEDWATER ISOIATIN A

e a.

Manual Initiation 2

1 2

1,2,3,4 18 g y tic Actuation 2

1 2

1,2,3,4 13, 36 b.

m E

c.

Containment 3

2 2

1,2,3 14 E

Pressure-High

$M d.

Pressurizer 3

2 2

1, 2, 38 14 l

8Y Pressure-I m EU U

e.

Im Steamline Pressure o

'Ihree Icops 3/ loop 2/ loop 2/ loop 1, 2, 38 14 Operating any loop any loop

'Iko loops 3/ loop 2/ loop any 2/any 1, 2, 3#

15 operating operating operating loop loop i

R o

TABLE 3.3-3 (Oontinued)

ENGINEERED SAFIHY FEATURE PCIUATIN SYSITH INSTRUME2 CATION -

1 i

W I

MINIM N y

10fAL NO.

QIAWELS OIANNEIS APPLICABLE d

FUNCTIONAL UNIT OF OIANNELS 10 TRIP OPERABLE MJDES ACTIN e

E M

4.

STEAM LDE ISOLATION w

2/ operating 1,2,3,4 18 a.

Manual 2/ steam line.

1/ steam line steam line I

b.

Automatic 2

1 2

.1,2,3,4 13 l

y Actuation Iogic j

3R p*

c.

Containmnt Pressure 3

2 3

1,2,3 14 l

Cy Intennediate-Ifigh-liigh l-S5 I

y d.

Im Steamline Pressure y

Three Icops Opera-3/ loop 2/ loop 2/ loop 1, 2, 38 14 l

ting (Inop Stop Any loop Any loop O

Valves Open) t iko Inops 3/ loop 2/ loop any 2/any 1, 2, 3#

15 i

Operating operating operating

' loop loop l'

e, liigh Steam Pressure 3/ loop 2/ loop 2/ operating 3##, 4 37 l

Rate any loop loop e

m

TABLE 3.3-3 (Continued) -

DIGINEERID SAFE 1Y FEA7URE ACIUATION SYSTDI INSTMNENPATICN m

N

.QiAt@lE M OIANNEM APPLICABE m

70 PAL NO.

FUNCTIONAL UNIT OF OIANNEM 70 TRIP OPERABLE F0 DES' ACTION

$e E

5.

TURBINE TRIP & FEEIMATER ISOIATIO4 i

e a.

Steam Generator 3/ loop-2 loop in 2/ loop in 1, 2, 3 14 Water IcVel-any oper-each oper-H Iligh-Iligh, P-14 ating loop ating loop l

r g

6.

IDSS OF POWER oya a.

4.16kv Bus 1/4.16kv Bus 1/4.16kv Bus 1/4ky Bus 1, 2, 3, 4 33

$2

1. Ioss of Voltage "u

(trip feeder) g8 2.

Ioss of Voltage me (start diesell 1/4.16kv' Bus 1/4.16kv Bus 1/4kv Bus 1, 2, 3, 4 33 N

y b.

Grid Degraded Voltage (4.16kv Bus) 2/4.16kv Bus 2/ Bus 2/ Bus 1,2,3,4 34 c.

Grid Degraded Voltage (480v Bus) 2/480v Bus 2/ Bus 2/ Bus 1, 2, 3, 4 34

' e~

TABE 3.3-3 (Continued)

ENGINEERED SAFEIY FEA'IURE N3UATION SYfrPEM INSTRIMENPATIN en.

MINIM E

'IUPAL NO.

GAWEIS GAWELS APPLICABLE 4

FUNCPIONAL UNIT -

OF QMNNEIS

'IO TRIP OPERABLE MJDES ACPIN E*

8.

ESF INPERIl]CKS e

a.

Reactor Trip, 2

1 2

1,2,3 38 y

P-4 e

b.

Pressurizer Pressure, P-11 3

2 2

1,2,3 38 h

c.

Iow-Im Tavg, P-12 3

2 2'

1, 2, 3 38 MR a>

bY 85 G"

O

Table 3.3-3 (Continued TABLE N0 RATION

Trip function may be bypassed in this 1G E below P-ll.

1. Trip function autanatically bypassed above P-ll, and is bypassed belou P-ll when Safety Injection en low steam pressure is not manually bypassed.

1. 1. 'Ihe channel (s) associated with the protective functions derived frcm the out of service Peactor Coolant Icop shall be placed in the tripped mode.

ACTION STATHENTS ACTION 13 With the number of OPEPABLE Channels one less than the Total Nurtber of Channels, be in HOT STANDBY within six hours and in COLD SHUIDOWN 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 two hours for surveillance testing per Specification 4.3.2.1.1.,

provided the other channel is operable.

ACTIN 14 With the number of OPERABLE Channels one less than the Total Number of Chanrels:

a.- Below P-ll or P-12, place the inoperable channel in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; 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 exceeding P-11 or P-12; otherwise be in at least hor STANDBY within tre following six hours.

b.

Above P-ll and P-12, place the inoperable channel in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; operation may continue until performance of the next required GANNEL FUNCTICNAL TEST.

ACTION 15 With a channel associated with an operating loop inoperable, restore the inoperable channel to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in HOP SHtJIDOWN within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; however, one channel associated with an operating loop e

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 4.3.2.1.1.

ACTION 16 With the number of OPERABLE Channels one less than the Total Number of Channels:

a.

Below P-ll or P-12, place the inoperable channel in the bypass condition; 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 exceeding Pil or P-12; otherwise be in at least HOP SHUTDOWN within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

BEAVER VALLEY UNIT 1 3/4 3-20 PEOPOSED TORDING L-

TABLE 3.3-3 (Continued) b.

Above P-ll or P-12, demonstrate that the Minimum Channels OPERABLE requirement is met within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; operation may continue with the inoperable channel bypassed and 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 testing per Specification 4.3.2.1.

ACTI N 17 -

'With less than the Minimum Channels OPERABLE, operation may continue provided the containment purge and exhaust valves are maintained closed.

. ACTION 18 --

With the nurter 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 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 cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

ACTION 33 -

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

ACTION 34 -

With the nurter of OPERABLE Channels one less than the Total Number of Channels, STARIUP and/or PCWER OPERATION may proceed until the performance of the next required Channel Functional Test provided the inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

AcrION 36 -

The block of the autmatic actuation logic introduced by a reset of safety injecticn shall be rer:mM 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. Manual block permitted after Safety Injection System and P-4 reset.

Otherwise, the requirements of action statement 13 shall have been met.

ACTION 37 -

With the number of OPERABLE channels one less than the Total Nurter of channels, STARIUP and/or POWER OPERATION may proceed provided the following conditions are satisified.

a.

'1he inoperable channel is placed in a tripped condition within one hour.

b.

The Minimum Omnnels OPEPABLE requirements 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.

AcrION 38 -

With less than the Minimum Nu:ter of Channels CPEPABLE, within one hour determine by observation of the associated permissive annunciator windcw(s) (bistable status lights or cmputer 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 PRCPCSED WORDING i

3 TABE 3.3-4 (Continued) 4 en 9-ENGINEERED SAFETY FENIURE Nm]ATION SYSITM INEFFIDGENTATION TRIP SETITOINTS n

Ner Q

FUNLTICNE IMIT

'IRIP SETPOINT ALIDRBLE VAwES 9h 8.

ESF INTERIOCKS e

a.

P-4 N/A N/A b.

P-11 4 2000 PSIG g 2010 PSIG m

c.

P-17

-2 541*F

_ 539*F 2

mu Ok e

OY w~

U V Yo I

i 1

4

.t

)

R 1

.)

3 a

TABLE 4.3-2 (Continued)

DCINEERED SAIT1Y FFA'IURE JCIUATION SYS'ITM INSTRLNENPATION SURVEIIIANCE REQUIRDENFS M

M CHAPNEL PODES IN MIICH g

OlNelEL OIAl#3EL EUNCTICNAL SURVEILIANCE p

FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED El I

8.

ESP INTERIDCKS g

H a.

P-4 N/A N/A R

1, 2, 3 e

b.

P-11 N/A R

M 1,2,3 c.

P-12 N/A R

M 1,2,3 m

O

$N*

't

!! M B"

uo 4

m

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3; [ + Q._ f f. ? ? A} jyng\\

,i m.%#y ' g.,.. ' Mf, Pr i

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1 1

3/4.3 INSTFUMENIATICN BASES 3/4.3.1 and 3/4.3.2 PFum;nVE AND ENGINEFRED SAFETY FEAnmES (ESF)

INsnGEt7fATICN 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 cmbination thereof exceeds its setpoint, 2) the specified coincidence logic is maintained, 3) sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance, and 4) sufficient system functional capability is available for protective and ESF purposes frca 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 assurptions used in the accident analyses.

h surveillance requirements specified for these systems ensure that the overall system functional capability is maintained ccrrparable to the original design standards. The periodic surveillance tests perforned at the minimum frequencies are sufficient to derrenstrate this capability.

h measurement of response time at the specified frequencies provides assurance that the protective and ESF action function associated with each channel is ccrnpleted 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.

Pasponse tine may be demonstrated by any series of sequential, overlapping or total channel test measurements provided that such tests denenstrate 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 replac'ement sensors with certified response times.

The Engineered Safety Feature Actuation Systen interlocks perform the following functions:

P-4 Beactor tripped - Actuates turbine trip, closas main feedwater valves on T below setpoint, prevents the opening of the main avg feedwater valves which were closed by a safety injection or high steam generator water level signal, allows safety injection block so that ccrponents can be reset or tripped.

Peactor not tripped - prevents manual block of safety injection.

P-11 Above the setpoint P-ll autcoatically reinstates safety injection actuation on Iow pressurizer pressure, automatically blocks steamline isolation on high steam pressure rate, enables safety injection and steamline isolation on (Iccp Stcp Valve Cpen) with low steamline pressure, and enables auto actuation of the pressurizer PCRVS.

BE,WER VAILEY - UNIT 1 B 3/4 3-1 PROPOSED NOPDING

e "y

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Q,'

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^P-ll, Continued i

ll l%

g.

_w e

J ' "'77 - 'C' Below the setpoint P-ll allows the manual block of safety injecticn actuation on low pressurl ei pr ssure, allows manual block of

'j g-safety injection and steamlih4 isolation on (Icop Stop Valve Open) with Iow steafalir.a pressure eand enabling steamline isolation on 0.

f-I 61 high steara pressure rate, autmatically disables auto actuation of

/

the - pressurizer' PORV's unless the - Reactor Vessel Over Pressure

,Pr.atect:i,on Systen is in; service.

f P-12

' Above the set % int P-12' autmatically reinstates an aming signal to the steam dunp system.

Belo.r the setpoint P-12 blocks steam

~~

~

dunt and allads unual bypass of the-steam dump block to cooldown

..condenscr du p valves.

i s

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J a #

4

,o r.<,,

34-u s

w%

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d 7

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4 l

4 9

1

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BEAVER VALLEY - UNIT 1

.B 3/4 3-la PPorCSED VDRDDG wF P%

.?

e ATTACHMENT B Safety Evaluation Proposed Change Request No. 86, Revision 3 amends the Beaver Valley Power Station, Unit No.1 Technical Specifications, Appendix A to address the NRC comments identified by letter dated March 13, 1984.

Description and Purpose of Change i

This proposed change is intended to provide further clarification of both the Limiting Conditions for Operation and Surveillance Requirements by incor-parating(ESF) Instrumentation tables.the appropriate interlocks into the Reactor Trip and Feature i

i 1.

Table 2.2-1 3 age 2-7 revised in accordance with Enclosure A unctional Unit 20, Reactor Trip System Interlocks, this was added in response to NRC staff recommendation 1,

and a note was added in parentheses to denote that the trip setpoints and allowable values are based on ascending power.

sage B 2-8 The Bases have been revised to define the functions of the teactor Trip System Interlocks.

2.

Table 3.3-1 page 3/4 3-2 revised in accordance With Enclosure B a.

Functional Unit 1, Manual Reactor Trip, Change Applicable Modes from 1, 2 and

to 1, 2, 3*, 4*, 5" in accordance with NRC staff recommen-dation 15.b.

b.

Functional Unit 2, Power Range Neutron Flux; 1.

delete note (1) added by our previous submittal 2.

add the Low Setpoint and a new note (1), Trip function may be manually bypassed in this MODE above P-10, denoted on page 3/4 3-5.

This is in accordance with NRC staff recommendation 3.

c.

Functional Unit 5, Intermediate Range Neutron Flux; 1.

delet.e note (2) added by our previous submittal II) 2.

change Applicable Modes from 1, 2 and

to I

, 2, 3*, 4*, 5*

and add note (1), Trip function may be manually bypassed in this MODE above P-10, denoted on page 3/4 3-5.

This is in accordance with NRC staff recommendation 4.

d.

Functional Unit 6, Source Range Neutron Flux; I

delete note (3) added by our previous submittal and replace with (Below P-10).

This change is in accordance with NRC staff recommendation 2.

._sr._

x y

-Safety Evaluatioii 1A-86, Rev f3 Paga 2

d. Continued :

change App (licable Modes from 2# and

to 2(2) 2.

3*, 4*, 5* ar.d add note 2)-, Trip function may be manually bypassed in this

MODE ao'ove P-6, denoted on page 3/4 3-5.

3.

delete t/ note, High voltage to detector may be de-energized above P-6, since the note (2) added above specifies the applica-ble permissive.xThis is in accordance with NRC staff recommen-dation 4.

page 3/4 i-3',. revised.in accordance with Enclosure B a.,

F6nctional. Unit 14, Steam Generator Water Level-Low-Low:

1., delete note 4 ~added by our previous submittal and add (Loop Stop

~ Valve Closed) as specified by NRC staff recommendation 6 and to

be consistent with the method used in identifying permissives.

2.

delete "in ani ~ operating loops" under the column Channels to Trip and delete "in each operating loop" under the column Minimum Channels Operable. since the notation in. parenthesis

~added by 1 above specifies the permissive condition for' the Steam Generater Water Level-Low-Low trip as shown ancL does not need to be.further defined as those. in an operating loop. This is in accordance with NRC staf ? recommendation 15.C.

page 3/4 3-4, revised in accordance wif.h Enclosure B a.

Functional, Unit 18, Turbine Trip, delete note (5) added by our

~ previcus submittal an( add ( Above ' P-9) to define the applicable permissive in. accordance with NRC staff re' commendation 2.

b.

' Functional. Unit 19, Safety Injection Input from-ESF, delete note (6) added by our previous submittal, in response to NRC staff recommenda-tion 8.

c.

Functional Unit 2i; Reactor Trip Breakers, change-Applicable Modes

'from 1, 2*~ ta 1, 2, 3*^, 4*, 5* in accordance with NRC staff recomen-dation 15..a.

~

d.

Functional Unit 22, Automatic Trip Logic, changd Applicable Modes from 1, 2* to 1, 2, 3*, 4*, 5* in acccrdance'with NRC staff recommen-dation 15.s.-

e.

Functional Unit 23, Reactor Trip System Interlocks, has been added to define tne permissives and reflect the change to Table 2.2-1 in

'accordance with NRC staff.reccamendation 1.

i e v

Safety Evaluation 1A-86, Rev. 3 Page 3 page 3/4 3-5 revised in accordance with Enclosure B such that note (1) encompasses the recommended table notation # and note 2) encompasses the recommended table notation ## to denote when the applit

.J trip functions may be manually bypassed.

I page 3/4 3-7 and 3/4 3-8 delete the P.eactor Trip System Interlocks as presently described in accordance with NRC staff recommendation 1, since the interlocks have been incorporated into the applicable tables and now more appropriately indicate the conditions under which protective function may be manually bypassed as well as those under which manual bypasses are automatically removed.

3.

Table 4.3-1 page 3/4 3-11 revised in accordance with Enclosure C a.

Functional Unit 2, Power Range Neutron Flux, has been revised to include the Low Setpoint to define the separate channel operability and surveillance requirements for these functions to reflect the addition of the low setpoint channel to Table 3.3-1.

b.-

Functional Unit 5, Intermediate Range Neutron Flux; 1.

add M(7) under the column Channel Functional Test to include a requirement for monthl with Table Notation (7)y testing when below P-10 in accordance added to page 3/4 3-13.

2.

Change Applicable Modes from 1, 2 and

to 1, 2, 3*, 4*, 5* in accordance with NRC staff recommendation 4.

c.

Functional Unit 6, Source Range Neutron Flux; 1.

add (Below P-10) to specify permissive applicability in accordance with NRC staff recommendation 2.

2.

add M(8) under the column Channel Functional Test to include a requirement for monthly testing when below P-6 in accordance

.with Table Notation-(8) added to page 3/4 3-13.

3.

change Applicable Modes from 2, 3, 4 and.5 to 2, 3*, 4* and 5*

in accordance with NRC staff recommendation 15.a.

d.

Functional Unit 9, Pressurizer Pressure - Low, add (Above P-7) to specify the applicable permissive in accordance with NRC staff recommendation 2.

e.

Functional Unit 11, Pressurizer Water Level-High, add (Above P-7) to specify the applicable ' permissive in accordance with NRC staff recommendation 2.

y.

Safety Evaluation IA-86, Rev. 3 Page 4 page 3/4 3-12 revised in accordance with Enclosure C; a.

Functional Unit 16, Undervoltage - Reactor Coolant Pumps, add (Above P-7) to specify the applicable permissive in accordance with.NRC staff recommendation 2.

b.

. Functional Unit 17, Underfrequency - keactor Coolant Pumps, add (Above P-7) to specify the applicable permissive in accordance with NRC staff recommendation 2.

c.

Functional Unit 18, Reactor Trip, add (Above P-9) to specify the applicable permissive in accordance with NRC staff recommendation 2.

~

d.

Functional Unit 21, Reactor Trip Breakers, change Modes from 1, 2* to 1, 2, 5* in accordance with NRC staff recommendation 15.a.

e.

' Functional Unit 22, Automatic Trip Logic, Change Modes from 1, 2* to 1, 2, 5* in accordance with NRC staff recommendation 15.a.

f.

Functional Unit 23, Reactor Trip System Interlocks, has been added to identify surveillance requirements consistent with Table 3.3-1, note M(9) - identified on page 3/4 3-13, requires monthly Channel Func-tional testing of these interlock channels when below the interlock trip setpoint.

page 3/4 3-13 revised in accordance with Enclosure C by adding Table Notation notes (7), (8) and (9) to reflect the addition of these notes to Table 4.3-1.

4.

Table 3.3-3 page 3/4 3-15 a.

Functional Unit 1, Safety Injection and Feedwater Isolation item b.

Automatic Actuation Logic 1.

delete note (1) added by our previous submittal 2.

add Action 36, in response to NRC staff recommendation 9, requiring SI reset within one hour of an inadvertent safety injection actuation; providing stable plant conditions are attained.

An additional sentence was added to this action statement, Manual Block permitted after Safety Injection System and P-4 reset, this was done to identify the block applicable to this plant condition, page 3/4 3-18 a.

Functional Unit 4, Steamline Isolation item e. High Steam Pressure Rate, change Action 18 to Action 37-in accordance with NRC staff recommendation 10.

Since the coincidence is 2/3 logic, this action statement requires the failed channel to be placed in trip and allows the inoperable channel to be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveil-lance testing of the other channels.

r v+

Safety Evaluation 1A-86, Rev. 3 Page 5 page 3/4 3-19 Functional Unit 5, Turbine Trip and Feedwater Isolation, item a. Steam Generator Water Level:

delete note (2) added by our previ-ous submittal, since NRC staff recommendation 11 states that N-1 loop operation changes should not be considered in this response.

Add P-14, since this permissive is defined by this function.

page 3/4 3-19b Functional Unit 8, ESF Interlocks, was added in response to NRC staff recommendation 14 and Enclosure E.

Action 38 applicable to these interlocks is identical to Action 12 in Table 3.3-1.

page 3/4 3-21 Delete the Engineered Safety Feature Interlocks in accor-dance with NRC staff recommendation 1, since the interlocks have been incorporated into the applicable tables and now more appropriately indi-cate the conditions under which protective functions may be bypassed as well as those under which manual bypasses are automatically removed.

Action 36, 37, and 38 have been added to reflect the changes to Table 3.3-3.

5.

-Table 3.3-4 page 3/4 3-24b has been added to incorporate Functional Unit 8, ESF Interlocks, and specify the applicable trip setpoints and allowable valves for P-ll an P-12 in accordance with Enclosure D.

P-4 was omitted from

-this table since no trip setpoint or allowable value is applicable.

6.

Table 4.3-2 page 3/4 3-31b has been added to incorporate Functional Unit 8, ESF Interlocks in accordance with Enclosure F.

The Channel Functional Test for P-4 cannot be performed at power, therefore, the test will be performed at R frequency.

7.

Jage B 3/4 3-1 The Bases have been revised to define the functions of the Engineered Safety Feature Actuation System interlocks.

8.

Section 4.1.1.1.1.g and 4.1.1.2.c. changes described in NRC staff recommendation 14.b and identified in Enclosures B and G were not included in this change request.

It is felt that the present location of the Source Range Neutron Flux requirements during plant shutdown conditions is appropriate and the change could cause confusion for plant operators.

Basis 1.

Is the probability of an occurence or the consequence of an accident or malfunction of equipment important -to safety as previously evaluated in the UFSAR increased? No.

Reason The proposed revisions are administrative in nature and do not physic' ally change plant safety-related systems, components or structures.

The changes are being made to identify conditions under which operating bypasses will block reactor trip or engineered-safety feature actuation

.c Safety Evaluation 1A-86, Rev. 3 Pag) 6 Basis,(Continued) channels and will not affect the function of any equipment or systems important to safety as addressed in the UFSAR Section 7.2, Reactor Trip System or Section 7.3, Engineered Safety Features System.

The changes provide further clarification of both limiting conditions for operation and surveillance requirements consistent with the UFSAR equipment design and operating requirements.

The interlock t.ri p setpoints have been revised in accordance with standard technical specification format to

'specify the interlock trip setpoints and allowable values to more clearly define the setpoints in a conservative direction by taking into account the applicable errors associated with the instrumentation channels.

2.

Is the probability for an accident or malfunction of a different type than previously evaluated in the UFSAR created? g Reason The proposed changes are administrative in nature and do not physically change plant safety-related systems, components or structures, therefore, the changes will not create the possibility for a new type of accident or malfunction of a different type than any previously evaluated in the UFSAR sections addressed above or the accident analysis of Section 14.

3.

Is the margin of safety as defined in the basis for any Technical Specification reduced? No Reason The Technical Specification BASES for the revisions addressed above will not be affected by the proposed changes, as none of the systems or compo-nents will be physically changed or their function altered in any way.

The changes provide additional clarification to enhance the effectiveness of the specification and provides consistency between the Reactor Trip and ESF requirements. Therefore, the margin of safety inherent in the appli-cable bases will not be reduced.

4.

Based on the above, is an unreviewed safety question involved? M Conclusion The proposed changes provide further clarification of both Limiting Conditions for Operation and Surveillance Requirements consistent with the

. equipment design and operating requirements as described in the UFSAR.

The changes are administrative in nature and do not involve physical changes to any plant safety-related systems, components or structures, will not increase the likelihood of a malfunction of safety-related equipment, increase the conse-quences of an accident previously analyzed, nor create the possibility of a malfunction different than previously evaluated in the UFSAR.

These changes are being made to address the NRC comments and recommendations provided by letter dated March 13, 1984.

f. -

_ _6 -

jf Safety Evaluation 1A-86, Rev. 3 i o-Page 7

-4.

i<-_

. Based on the-considerations above, the proposed changes have been deter-mined to be safe and do not involve an unreviewed safety question.

t m

.me O

4

ML20093E753

Text

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