ML20198P336

Proposed Tech Specs Reducing Repeated Alarms,Rod Blocks & Partial Reactor Trips That Continue to Manifest,During Beginning of Cycle Operation Following Refueling Outages

ML20198P336
Person / Time
Site:	Callaway
Issue date:	10/31/1997
From:	UNION ELECTRIC CO.
To:
Shared Package
ML20198P335	List: ML20198P332 ML20198P336
References
NUDOCS 9711070089
Download: ML20198P336 (35)

Text

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ULNRC 3673 e.

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, ATTACIIMENT T11REE l,

PROPOSED TECllNICAL SI'ECIFICATION REVISIONS i

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l 971107 971031 -

i PDR K 05000483 P PDR ,

- . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ . . . . _ . _ _ __._____ . - . . . . _ _ ._. _.l

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C TABLE 2.2-1 h REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS 9

r R TOTAL SENSOR ERROR e

FUNCTIONAL UNIT ALLOWANCE (TA) 1 In TRIP SETPOINT ALLOWABLE VALUE E 1. Manual Reactor Trip N.A. N.A. N.A. N.A. N. A.

• 4 2. Power Range, Neutron Flux

~

a. High Setpoint 7.5 4.56 0 5109% of RTP*- 5112.3% of RTP*

b. Low Setpoint 8.3 4.56 0 s25% or RTP* $28.3% of RTP*

3. Power Range, Neutron Flux, 2.4 0.5 0 $4% of RTP* $6.3% of RTP*

High Positive Rate with a time with a time constant 22 constant 22 seconds seconds

4. Deleted

';' 5. Intermediate Range, 17.0 8.41 0 525% of RTP* $35.3% of RTP*

^

Neutron Flux

6. Source Range, Neutron Flux 17.0 10.01 0 s10' cps $1.6 x 10' cps  !

7. Overtemperature AT .-9r3- N. A. M-N.A. 4-43-MA.See Note 1 See Note - I

I.2"^^^

8. Overpower AT --G-e- N. A. Je9&N.A, 6&N.A.See Note 3 See Note 4 l

3. Pressurizer Pressure-Low 5.0 2.21 2.0 21885 psig 21874 psig

, 10. Pressurizer Pressure-High 7.5 4.96 1.0 $2385 psig. s2400 psig

_. 2 11. Pressurizer Water Level- 8.0 2.I8 2.0 $92% of $93.8% of 2h High instrument span instrument span

% 12. Reactor Coolant flow-Low 2.5 1.38 0.6 290% of loop 288.8% of loop

= minimum minir!m

? measured flow ** measured flow **

IM b

• RTP - RATED THERMAL POWER Minimum Measured Flow - 95,660 gpm Tu Allu ...ccs (t_y eraturc = d prc-' re, 2070Ctb?Old

-e TABLE 2.2-1 (Continued) -

O REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS T~

E SENSOR C TOTAL ERROR

. FUNCTIONAL UNIT ALLOWANCE (TA) Z (5) TRIP SETPOINT ALLOWABLE VALUE C

5

13. Steam Generator Water Level Low-Low

(/2.+/*/,

a. Vesse' AT Equivalent e- 2 +e- -4r6rr < Vessel AT < Vessel AT l

1-+0f RTP y.A. g. A. N.A. Equivalent to Equivalent to Vessel AT (Power 1) -4N RTP 13.9I RTP

/2.4/*/,

Coincident with Steam Generator Water 20.2 17.58 2.0 -> 20.2% of Marrow > 18.4% of Narrow m level Low-Low (Adverse fiange Instrument liange Instrument J, Containment Environment) Span Span and

- Containment Pressure - 2.8 0.71 2.0 1 1.5 psig 1 2.0 psig Environmental Allowance Modifier

$" OR R Steam Generator Water 14.8 12.18 2.0 > 14.8% of Narrow > 13.0% of Narrow 1 3 Level Low-Low (Normal Ringe Instrument Range *nstrument l l

Containment Environment) Span Span 5

With a Time Delay. (t) < 232 seconds

< 240 seconds

.N

.'  ?

c e

TABLE 2.2-1 (Continued) h REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS 2-5 SENSOR TOTAL ERROR FUNCTIONAL 'dNIT ALLOWANCE (TA) Z (5) TRIP SETPOINT ALLOWABLE VALUE E

Q 13. Steam Generator Water

- Level Low-Low (Continued) 12.+/%

b. -40tVRTP < Vessel aT -6:4- R- -+ < Vessel AT < Vessel aT Equivalent < RTP N.A. N.A. N.A. Equivalent to Equivalent to Vessel ai (Powe 2) M RTP 23.9% RTP 22.+1 %

Coincident with

• m Steam Generator Water 20.2 17.58 2.0 > 20.2% of Narrow > 18.4% of Narrow

& Level Low-tow (Adverse sange Instrinnent Nange Instrument Containment Environment) Span Span 7

. and Containment Pressure- 2.8 0.71 2.0 <_ 1.5 psig < 2.0 ps ig Environmental Allowance Modifier N

$ OR

& > 14.8% of Narrow > 13.0% of Narrow 3 Steam Generator Water 18.8 12.18 2.0

" Level Low-Low (Nonnal liange Instrument Range Instrument (

• Containment Environment) Span Span With a Time Delay, (t) < 122 seconds < 130 seconds Q

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1 -

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e TABLE 7.2-1'(Eontinued)

TABLE NOTATIONS n'

? ,

E NOTE 1: -OVERTEMPERATURE AT E

AT (1+r,5) }

e z 1 +r3 5 s AT, ( K,- K, (1 +r S) T i t

-T' + K 3 (P- P')- f,(AI)}

(1+r 2S) (1 +r3 5) 1 +r6S w

Where: AT- -

Measured AT; 1 +r,5 -

Lead-Lag compensator on measured AT; 1+r2S T,,7z -

Time constants utilized in lead-lag compensator for AT,r:18s,r,53s; l' -

Lag compensator on measured AT; 1+T3S

.u T3 -

' ' Time constant utilized in the lag compensator for AT, 3r - Os; ATo --

Indicated AT at RATED THERMAL POWER; K, -  !.15, /. / 950)

K 2

0.0251/*F; 1 +r, S -

.The function generated by the lead-lag compensator for T, dynamic 1+r55 . compensation; )

g 74,73 -

Time constants utilized in the lead-lag compensator for T,, 74 2 28s, -[

$ 73 5 4s; g T j

Average temperature,*F; '

2 1 -  !

P tag compensator on measured T ,;

+

1+r 6S  ;

? r3 -

Time constant utilized in the measured T , lag compensator, r, - Os;

.E' .

qp r

F

j 1l N

I I [

M.

4*

e y n: ht b M.

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T

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a c t m

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at Me t s u rP

- - a 0. /

eU r

T Rc r E e n

o b e 2 wR o

Hp t u l c pA T

Tn a l e h a

Di e h heS ER b s t t t TE l t r e

f n AW l

a i n o

ola RO h o p m

) sp t P s y R r ogn n t t

e ,

E t eL n S b W ci r cA i o t eu r e M. p p n O p t i

r c

e d t

P e T p L de s eE r H S T t e

p A mn aT A f, S 6

topo i

r M ) bl T e, p R e t s oa h y i

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d e

E r

u s

oe b r do t

T A J, 4 T

r u H s nt d

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T dt as e /,  %.R e d

e n

D e

r nn a e t

i ht O E t it p ab u u

n n

o E T g pmu e Q ,

m_  ?

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C A n  ;

o t t r

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R it s h 0 a1 nn c C SN t a

r e s ei e d wa t 2 d n eL eA s L_ O p , ,d na t I

g v

g o or we t r On a hR a: cM x

eR i

d T a i a t a eu t e A s bs a

, E b E e T p C r y e QH c E

T O d , R ep ee c

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i vW O T x L e e l a o nm f t - e N c r i aP tD B

unm jt g

A E n s i en r f c eL aE t o

eo .e es o mro T L e ,

p /e,) nA f T n B

r e  :

g r f f

i d f A- s eM oA l l

A f eR a T e s pr N ( s i

n de s Gef

r r

oR d h R /p e g

(

F 61 z i i

s t a

r d a t

eb -

e+ rEH t

iT s

i t

uta ne t s

n r p e ad ce /*, gu

'4 1 u c i

bD aa l i

o 0 s 5 a i t ae OE mvs p

8 0 esr 32 alp 8

dne2 i l ce / "t h t - T et S t

e Mf tA he s

- 5 0 P 2 L No aR hi t f p t e i s t t t o i r

f b n e v: aa a T s = = = = o o el R h

t e h%

t nt eaE t u 3 m u

os wh W na l t n7 i

t n t ev e9 m b mO ci a e c r s c r2 i

x n g oP u t et e p by a f ht boL p if m

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a c ae l

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it

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tb o oH Ft T F3 Fo e r h a

n im c o - da i) ) )

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T E g O N

T O

N O E e>:s $ I e::z y w y" go[s P y~ Mhr 4 f l!Ill m

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-e Tf4BLE 2.2-1 (Continued)

TABLE NOTATIONS (Continued) 9 ..

r-9 NOTE 3: OVERPOWER'AT-55 AT (1 +r,5) 1 757 g i e s AT, { K - K3 T - K [T - 7"]- f (AT)}

2 34 (1 +72 5) 1 +r3 5 1 +r75 1+r,S 1+r,S i , , . .

time Where: AT - Measured AT; 1+r,S - Lead-Lag compensator on measured AT; 1+r75 r,,7z -

Time constants utilized in lead-lag compensator for AT,r 18s,7 2s3s; m 1 - Lag compensator on measured AT; y 1+r35 73 -

Time constant utilized in the lag compensator for AT, 3r - Os; AT, - Indicated AT at RATED THERMAL POWER; K4 -

? .000, /./073; l g p_ K3 -

0.02/*F for increasing average temperature and 0 for decreasing average

~g temperature; g _r 7_5 -

The function generated by the rate-lag compensator for T, dynamic 1+r rS Compensation; 5

{ 77 ' -

Time constant utilized in the rate-lag compensator for T,, 77 2 los; g 1 -

Lag compensator on measured T,;

.-g 1+r65 r, -

Time constant utilized in the measured T , lag compensator, 7- Os; E

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

---

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-(-

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c j TABLE 2.2-1 (Continued) n

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TABLE WTATIONS (Continued) 1: E

': E NOTE: 3 (Continued) f K, l 0.0015/*F for T > T* and K - O for T $ T*;

'$w T -

Average Teeperature, *F;

~

T* -

Indicated T,y at RATED THERMAL POWER (Calibration temperature for AT instrtmentation, s 588.4*F);

S -

i.aplace transform operator, s; and f z(AI) -

O for all AI.

NOTC 4:

The channel's maximum Trip Setpoint shall'not exceed its computed Trip Setpoint by more than [

] ';+ 4,44;,0f ST span (/,P2% M, i

5 f.)l*/.

t

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ab R8. -

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f do .

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

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7ABtt 4.3-1 (Continued)

IgtE NOTATIONS i

Only if the Reactor Trip System breakers happen to be closed and the Control Rod Drive System is capable of rod withdrawal.

. # The specified 18 month frequency may be waived for Cycle 1 provided the surveillarce is performed prior to restart following the first refueling outage or June 1, 1986, whichever occurs first. The provisions of Specification 4.0.2 are reset from performance of this surveillance.

1. 1. Below P-6 (Intermediate Range Neutron Flux interlock) Setpoint.

1. 1. 1. Below P-10 (Low Setpoint Power R&nge Neutron Flux interlock) Setpoint.

(1) If not performed in previous 31 days.

(2) Comparison of calorimetric to excore power indication above 15% of RATED THERMAL POWER. Adjust excore channel gains consistent with calorimetric power if absolute difference is greater than 2%. The provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

(3) Single point comparison of incere to excore AXIAL FLUX DIFFERENCE above 15% of RATED THERMAL POWER. Recalibrate if the absolute difference is greater than or equal to 2%. The provisions of Specification 4.0.4 are r ,

not applicable for entry into MODE 2 or 1.

(4) Neutron detectors may be excluded from CHANNEL CAllBRATION.

-) (5) For Source Range detectors, integral bias curves are obtained, evaluated, and compared to manufacturer's data. For Intermediate Ran Range channels, detector plateau curves shall be obtained,geevaluated, and Power and compared to manufacturer's data. For the Intermediate Range and Power Range Neutron Flux channels the provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

(6) Incore - Excore Calibration, above 75% of P.ATED THERMAL F0WER The provisions of Srecification 4.0.4 a~e not applicable for entry into MODE 2 cr 1. Determination of the loop specific vessel AT valudi)hould be made when performin the incore/Excore quarterly rec ibraE on, under steady state concit ons. .

ang G (7) Each train shall be tested at least every 62 days on a STAGGERED TEST

.EASIS. The TRIP ACTUATING DEVICE OPERA 110NAL TEST shall independently verify the OPERABILITY of the Undervoltage and Shunt Trip Attachments of the Reactor Trip Breakers.

(8) Deleted (9) Quarterly surveillance in MODES 3*, 4*, and 5* shall also include verification that permissives P-6 and P-10 are in their required state for existing plant conditions by observation of the permissive annunciator window. Quarterly surveillance shall include verification of the Boron Dilution Alarm Setpoint of less than or equal to an increase of 1.7 times the count rate within a 10-minute period. -

l

)

CALLAWAY - UNIT : 3/4 3-12 Amendment No.AS.28,2A,$1,94

A c

v _ .

TABLE 3.3-4 (Continued) n ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTR 1%tENTATION TRIP SETPOINTS

?"

E SENSOR S TOTAL ERROR TRIP ALLOWABLE FUNCTIONAL UNIT ALLOWANCE (TA) Z (S) SETPOINT f VALUE E 6. Auxiliary feedwater (Continued)

- d. Steam Generator Water Level Low-Low (Continued)

1) Start Motor-Driven Pumps

a. Vessel aT Equivalent -fr:9- 2 +2- -hffr < Vessel AT < Vessel A!

< RTP N.A. N.A. p/. A. Equivalent to Equivalent to R*

Yess .aT (Power-1) 43MF RTP 13.9% RTP 12.41 % . /2.41*4 Y Coincident with 3

O

~

Steam Generator Water 20.2 17.58 2. 0 . > 20.2% of Marrow > 18.4% of Narrow Level Low-Low (Adverse Range Instrument Range Instrument

" Containment Environment) Span Span 6nd Containment Pressure - 2.8 -0.71 2.0 -< 1.5 psig < 2.0 psig F Environmental Allowance 3 Modifier i

j OR E Steam Generator Water 14.8 12.18 2. 0 > 14.8% of Narrow > 13.0% of Narrow iiange Instrument

~

Level Lew-tow (Nonnal iiange Instrument-

$ Containment Environment) Span Span vi With a Time Delay, (t) < 232 seconds < 240 seconds I,

l jf(1Ijllllll1 ll c

w w ot ot rn rn o re re t

am N u am s T r N u d at f t g r n E nP os f t o L l eI n i

s os c BE el R %I p %I n e

. AU sa 4 s

. WL OA sv%

ei9 8gn e 0 0. e 3 gn 0

3 LV Vu 1 na 2 1 na 1 L o3 ap ap A <E2 >RS < >RS 1 S

T N w w I

O ot ot rn rn P re re T

E o am am s S

t Nu Nu d T r r n At f t g ft o P n osn i os c I T l e s n e R N elP %I p %I s T PI sat 2 N

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( ad i r e<F ( h ao a ao ke V t rLt tt rt t l E r u D t i e- n nn en e R e rn r ) ?,< nT w nwe ee nwe D E

E t a tt oi od/Pl e A eom GLn mmr nne eom e N w an t GLn m oue f. T al n t i ioi i I

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TABLE 3.3-4 (Continued) n ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS p.

E SENSOR S TOTAL ERROR- TRIP ALLOWABLE

[ FUNCTIONAL UNIT ALLOWANCE (TA) Z (5) SETPOINT VALUE E 6. Auxiliary Feedwater (Continued)

- d. Steam Generator Water Level Low-Low (Continued)

2) Start; Turbine-Driven Pump f,,4jg

a. Vess AT Equivalent -E-ft .+-97 < Vessel AT < Vessel AT 5 TP N.A. M.A. N.A. Equivalent to Equivalent to u Vessel AT (Power-1) M RTP 13.9* RTP 2 /2.41*/,

w Coincident with m

X Steam Generator Water 20.2 17.58 2.0 > 20.27, of Narrow > 18.4% of Narrow S Level low-Low (Adverse Range Instrument Range Instrument Containment Environment) Span Span and Containment Pressure - 2.8 0.71 2.0 ~~

< 1.5 psig ~

< 2.0 psig g Environmental Allowance

. Modifier E

2 OR 1 5

z ' Steam Generator Water 14.8 12.18 2.0 > 14.8% of Narrow > 13.0% of Narrow P Level Low-Low (Normal h nge Instrument Range Instrument Containment Environment) Span Span 3- With a Time Delay. (t) < 232 seconds

< 240 seconds l

!l l

l

,- .- 1 c

w. -

TABLE 3.3-4 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS E SENSOR

.5 TOTAL ERROR TRIP ALLOWABLE

[ FUNCTIONAL UNIT ALLOWAMCE (TA) Z (S) SETPOINT VALUE E 6. Auxiliary Feedwater (Continued)

- d. Steam Generator Water Level Low-Low (Continued)

2) Start Turbine-Driven

' Pump (Continued)

' 13.4f%

V

b. -iet RTP < Vessel AT e- - 2.72 - -h65- < Vessel aT < Vessel aT f g Equivalent < RTP N.A. g.A. g,A, fquivalant to Equivalent to l

• Vessel aT (Power ) M RTP- 23.9% RIP Y 2.2.4/% *~5 Coincident with g

Steam Generator Water 20.2 17.58 20' > 20.2% of Narrow > 18.4% of Narrow Level Low-tow (Adverse . Range Instrument Range Instrument Containment Environment) Span Span And g Containment Pressure - 2.8 0.71 2.0 < 1.5 psig

< 2.0 psig-

. Environmental Allowance Modifier

{

e A- OR z

? Steam Generator Water 14.8 12.18 2.0 , > 14.8% of Narrow > 13.0% of Narrow Level Low-Low (Normal Range Instrument Range Instrmacnt Q

. Containment Environment) Span Span With a Time Delay, (t) < 122 seconds

< 130 seconds

s

? .

2. 2 LIMIT!NG SAFETY SYSTEM SETTINGS

BASES 2.2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETPOINTS The Reactor Trip Setpoint Limits specified in Table 2.2-1 are the nominal values at which the Reactor trips are set for each functional unit. The Trip Setpoints have been selected to ensure that the core and Reactor Coolant System are prevented from exceeding their Safety Limits during normal operation end design basis anticipated operational occurrences and to assist the Engineered Safety Features Actuation System in mitigating the consequences of accicents.

The Satpoint for a Reactor Trip System or interlock function 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 Satpoints can be measured and calibrated Allow-able Values for the Reactor Trip Satpoints have been specified in Table 2.2-1.

Operation with Satpoints less conservative than the Trip Setpoint but within the Allowable Value is acceptable 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 uncer-tainties of the instrumentation to me'asure the process variable and the uncer-tainties in calibrating the instrumentation. In Equation 2.2-1, I + A + 5 the interactive effects of the errors in the rack and the sensor, and the "iasTA, measured" values of the errors are considered. Z, as specified in Table 2.2-1, 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 Reactor trip.

R or Rack Error is the "as measured" deviation, in percent sean, for the t affected channel from the specified Trip Setpoint. 5 or Sensor Error is eithe.'

the "as measured" deviation of the sensor from its calibration point or the value specified in Table 2.2-1, in percent span, from the analysis assumptions. .

1:r fu=th : which 5::: =1tiph b;ut v:h::, due t: cere den ^ par- ter -

- p ry!df e; 4;rt !! Se furtha, =ltf;h =h;; Nr ! ;r; =t'd whka ;r; d S M M M th! ;d = 0 h;;t :h= = h. ( h ; i t k ;;h = = ; t C h t h f. O pe!-t study fer pretection syste r previded fer justi* citica) Use of Equa-tion 2.2-1 allows for a sensor drift factor, an increased rack drift factor, and provides a threshold value For REPORTABLE EVENTS.

The methodo.ogy to derive the Trip Setpoints is based upon combining all of the uncertainties in the channels. Inherent to the determination of the Trio Setpoints are the magnitudes of these channel uncertainties. Sensors and other instrumentation utilized in these channels are expected to be cacaole of operat-ing within the allowances of these uncertainty magnitudes. Rack drift in excess of the Allowable Value exhibits the behavior that the rack has not met its allowance. Being that there is a small statistical chance that this will hacoen, an infrequent excessive drift is expected. Rack or sensor drift, in excass of the allowance that is more than occasional, may be indicative of more serious problems and should warrant further investigation.

CALLAWAY - UNIT 1 8 2-3 Amencment No. U

LIMITING SAFETY SYSTEM SETTINGS BASES

)

Jntermediate_and Source Ranae. Neutron Flux

' The Intermediate and Source Range, Neutrori Flux trips provide core protection during reactor startup to mitigate the consequences of an uncontrolled rod cluster control assembly bank withdrawal from a suberitical condition. These trips provide redundant orotection to the Low SetpointtripofthePowerRange,NeutronFluxchgnnels. The Source Range channels will initiate & Reactor trip at about 10 counts per second unless manually blocked when P-6 becomes active. The Intermediate Range channels will initiate a Reactor trip at a current level ecuivalent to approximately 25% of RATED THERMAL POWER unless manually blocket when F 10 becomes active.

Overtemperature AT The Overtemperature 4T tri all combinations of pressure, power, p provides core coolant protection and temperature, to prevent DNB for axial power distribution, provided that the transient is slow with respect to piping transit delays from the core to the temperature detectors, and pressure is within the range between the Pressurizer High and Low Pressure trips. The-Setpoint is automatically varied with: (1) coolant temperature to correct for temperature induced changes in density and heat ca)acity of water and includes dynamic compensation for piping delays from tie core to the loop temperature detectors, (2) pressurizer pressure, and (3) axial power distribution. With normal axial power distribution, this Reactor Trip limit is always below the core Safety Limit as shown in Figure 2.1-1. If axial peaks are greater than design, as indicated by the difference between top and bottom power range nuclear detectors, the Reactor trip is automatically reduced according to the notations in Table 2.2-1.

~ Zh/JrERT12-S /

0:lt: T , :: u:d-inth:Ove(temperature:ndOverpr(eer)ATtript, -

repre: rt:*the !005 "T" v:le: :: me::ered by the pl:nt for :::h leep. Rr

-th: :t rtup of : refurl:d : r: u til me::ur:d :t 100% R:t:d Th;rm:1 P=:r (PTP),Delt: T i: Siti:11y ::: =:d :t : v:1;; which i: con::rv:tively i n:r th:n th:,1::t me::ured l0: ': RTP Delt: T f:r :::b leep. TH:

mer::li::: :::F leep': AT tr i Sto the actual, operating conditions existing at the time of measurement, tius forcing the trip to reflect the equivalent full power conditions as assumed in the accident analyses. These differences in vessel A3,can arise due to several factors, the most f n n o n m i. v e m y m o u1 c v RCS loop flows greater than Minimum Heasured flow,

( and slightly asymmetric power distributions between quadrants. While RCS loop flows are not expected to change with cycle life, radial power s redistribution between_ quadrants may occur, resulting in small changes in Q 7 X loop specific vessel AT+ values. Accurate determination of the loop v)IspecificvesselATavalug)houldbemadewhenperformingtheIncore/Excore quarterly recalibrationTnd under steady state conditions (i.e., power distributions not affected by Xe or other transient conditions).

.tNMRT  :

The time constants utilized in the lag compensation of measured AT, 73 ,

g)gg and measured 1,The I300 NLL cards used for lag compensat t, are set in the field at 0 seconds. This setting corresponds to signals. Safety analyses that credit Overtemperature AT for protection must account for these field adjustable lag cards as well as all other CALLAWAY - UNIT 1 B 2-5 Auendment No, 28. R 102 Lk=~1DJ3DJnA

INSERT B 2 5(1)

. ATo and T', os used in the Overtemperature AT trip, represent the 100%

RTP values as measured by the plant for each loop. For the startup of a reRieled core, ATo is initially assumed at a value which is conservatively

. lower than the last measured 100% RTP ATo for each loop. Upon reaching 100% RTP, and during each quarterly incore Exetere CHANNEL CAllBRATION thereafter, ATo and T' are adjusted to be consistent with measured values for each loop. This normalizes each loop's Overtemperature AT trip INSERT B 2-5(2)

The Allowable Value, as specified in Note 2 of Tabla 2.2-1,is associated with the uncertainties in the process rack electronics. The Allowable Value provides a criterion for assessing the OPERABILITY of the process rack portion of the protection channel. Deviatbns in excess of the Allowable Value are indicative ofinstrumentation problems and should therefore result in an investigation of the Overtemperature AT process rack OPERABILITY for the affected channel, t

LIMITING SAFETY SYSTEM SETTINGS I

, BASES Overtemperature AT_(Continued)

~

first order lags (i.e., the combined RTD/thermowell response time and the scoop transport delay and thermal lag .

first order lag of less than or equal)to 6 seconds.The safety analyses use a total Overnower AT The Overpower AT trip provides assurance of fuel integrity fuel pellet melting and less than 1% cladding strain) under all(e.g., no possible overpower conditions, limits the required range for Overtemperature AT trip, and provides a backup to the High Neutron Flux Trip.

The Setpoint is automatically varied with: (1) coolant temperature to correct for temperature induced changes in density and heat capacity of water, and (2) rate of change of temperature for dynamic compensation for piping delays from the core to the loop-temperature detectors, to ensure that the allowable heat generation rate (kW/ft) is not exceeded. The '

Overpower AT trip provides protection to mitigate the consequences of various size steam breaks as reported in WCAP-9226, " Reactor Core Response to Excessive Secondary Steam Releases."

g .rh/ SERT A 3-4 I

).

D lt: T , ::

d in the 0/:f

-repre: nt: ,the 100% RTP v: 13 e .: p:r:ture m:::ured by the pkntand fer :::hOverpe(w~)

h p. fr "*^

- tS :t:rtup Of : refuele:' :Or: nti' ::::ured :t 100% ":ted Therm:1 P wcr (RTU , Deite T i; ir,itially e m::i c t : v:h d i:F it--centervatively

- hu:r th:n the,h :t :::ured 10M "TP Delt: T, fer es:S hep. Thit m :!ize  ::b hep': AT trip;!to the actual operating conditions existing at the time of measurement, thus forcing the trip to reflect the equivalent full power conditions as assumed in the accident analyses. These differences in vessel Akcan arise due to several factors, the most orovalent beino measur1:4 RCS loop flows greater than Minimum Measured Flow,

( and slightly asymmetric power distributions between quadrants. While RCS loop flows are not expected to change with cycle life, radial power redistribution between quadrants may occur, resulting in small changes in

"\ specific vessel ATavaluloop specific vesse: M alues. Accurate determination of the lo hould be made when performing the Incore/Excore CM s Tvh quarterly recalibration@and under steady state conditions (i

.e., power distributions not affected by Xe or other transient conditions).

1. ?,/fERT~

~

The time constants utilized in the lag compensation of measured AT, g ,

r , are set in the field at 0 seconds.

8 2~dI3) and measured T,T$e f3L0 NLL cards used for lag com corresponds to This setting signals. Safety anabses that credit Overpower AT for protection must account for these field adjustable lag cards as well as all o$ner first order lags (i.e., the combined RTD/thermowell response time and the scoop transport delay and thermal lag). The safety analyses use a total first order lag of less than or equal to 6 seconds. '

)

CALLAWAY - UNIT 1 B 2-6 Amendment No. 38. 102 t s.v. 1 h in O lM

INSERT B 2-6(1)

ATo and T", as used in the Overpower AT trip, represent the 100% RTP values as measured by the plant for each loop. For the startup of a refueled core, ATo is initially assumed at a value which is conservatively lower than the last measured 100% RTP ATo for each loop. Upon reaching 100% RTP, and durhig each quarterly incore-Excore CHANNEL CALIBRATION thereafler, ATo and T" are adjusted to be consistent with measured values y for each loop. This normalizes each loop's Overpower AT trip INSERT B 2-6(2)

The Allowable Value, as specified in Note 4 of Table 2.2-1, is associated with the uncertainties in the process rack electronics. The Allowable Value provides a criterion for assessing the OPERABILITY of the process rack portion of the protection channel. Deviations in excess of the Allowable Value are indicative ofinstrumentation problems and should therefore result in an investigation of the Overpower AT process rack OPERABILITY for the affected channel.

ULNRC-3673 ATTACilh!ENT FOUR CIIANGILS TO ULNRC-3578 A*ITACilhlENT 19 s

+

b

RTS Instrumentation 3.3.1 Table 3.3.1 1 (pege 3 of 6)

. Reactor Trip System instrumentation

. APPLICABLE MCDES OR OTHtt SPECIFit0 REQUIRED SURVElLLANCE FUNC110N CONDifl0NS CHANNELS CONDifl0NS RfoultfMENTS ALLQLt VALUE I 14 SG Water Level Low Low (continued)

c. Vessel af 1, 2 4 W SR 3.3.1.1 Equivalent and SR 3.3.1.7 Trip flee SR 3.3.1.10 Delay (1) ...., .i s Vessel af

-4gr+,em teJivalent Ed Vesse! af thhh (Power 1)

(2) 4,6 n r s s vesset af

.......;- Equivatont T

==

Vessel at (Power 2)

d. Contairment 1, 2 4 V SR 3.3.1.1 s 2.0 pois Pressure

• SR 3.3.1.7 ,

Environmental SR 3.3.1.10 Attowance Modifier

15. Not used

16. Turbine Trip

a. Low Fluid ill 1(II 3 P SR 3.3.1.10 a $39.42 Pressure SR 3.3.1.15 psig

b. Turbirie Stop IIII 4 P SR 3.3.1.10 a 11 open Valve Closure SR 3.3.1.15

17. Safety injection (SI) 1,2 2 trains 0 SR 3.3.1.14 NA Irout from Engineered Safety Feature Actuation System (ESFAS)

(continued)

(a) The Allowable Value deffnes the timiting safety system setting. See the Bases for the trip setpoints.

(j) Above the P 9 (Power Range Neutron Flux) Interlock.

(n) With a time delay 5 240 seconds.

(0) With a time delay s 130 seconds.

CALLAWAY PLANT ITS 3.3 17 5/15/97 I

i

RTS Instrtmentation 3.3.1 Table 3.3.1 1 (page $ of 6)

Reactor trip System Instrumentation

. kete it overt-rature at the overtosperature Af function Allowable Value shall not exceed the following setpoint by more than4rttrof g of spen (/,/S'I M

/,2 :rd/,

(1+ t,s) g (1+ t,s) 1 r, + g (F - 7,) - f (a I) ar (1+ 13 s) s a r' ' g- g (1+ T3 s) r 3 1 + 13 s, (1+ 1,s) j Where af is measured RCS af, 'F.

at is the indicated af at RTP, 'f.

skstheLaplacetransformoperator,sec*l. '

T la the measured RCS everage temperaturej 'F.

T' is the referenced T ,, et RTP, s 588.4 f.

P la the measure pressariter pressure, peig.

P' la the nominet RCS operating pressure e 2235 pels.

Kg s W /, / 60 K2 a 0.0251/'t K3 e 0.00116/psig tg a 8 sec 2 ' 3 8'8 '3e0 pc 14 a 28 sec 1

_t$ s 4 sec , - 1 6 e O sec

• 2le//*

f g(at) e 0.0325 h ( t

• Ab)) when - < 23% TP 0% of RTP when Ps * .b s RTP "h'" 4 RTP 0.02973 ((at

• Ab )

• t *Ab> gg

.here , .nd .repercd,Ninthe ,er . ,4 i e h.tve. of is. c. ore, respotiv.ty, .nd

.,..,isthyiot.ithetPowiRin reent ,1P.

. f,4

-21 /e8 s

CALLAWAY PLANT ITS 3.3 19 5/15/97

RTS Ins 0 'nentation 3.3.1 Table 3.3.1 1 (pese 6 of 6) .

Reector irlp System Instrissentation hata If Qvarnmaar AT 8

The herpower Af functitvi Allowable Value shtll hot exceed the follwing 1etpoint by more then 4 M 0f Af spen [/, /.2% gT/),

l,D/N

+ t,e) t t1,e) 1 1 I

a F-

• A F, < F - K, F ~ F ,, ~ f eta M '

(1 + t,e) 1 + t.e , K," K* (1 + t,e) ,1+t.e, (1 + t,e; l

Wheros af is measured RCS of, 'F.

At to the indicated of et RTP, 'F.

s a the LefLece transform operator, sec'I.

T le the measured ACS averess tagerature, *F.

f

• la the Indicated T,y, et RTP (Cellb etion tegerature for at instrtamentation), s $88.4*F.

K 4 s w/./073 K 5 a 0.02/'t for increasing f ,y, K6 a 0. M H/*7 when T e T' 0/'F when f s T*

- 0/'t for decreasing 1 ,y,

_tg a a see 12 s 3 sec- 13 e O see 16 e O sec 17 a 10 sec f.(SI) g e 0% RTP for all al.

s CALLAWAY PLANT ITS 3.3 20 5/15/97

ESFAS Instrumentation 3,3.2 Table 3.3.2 1 (page 5 of 6)

Ergineered Safety Feature Actuation System Instrumentation

~

. APPLICABLE HJOES OR OT)lfR SPECIFIED REQUIRED $URVEILLANCE ALLOW 4LE FUCTION CONDITIONS CMNNELS CCTITIONS REQUIREMENTS VALUE"'

6. Auxiliary Fe Mwater (contirued)

(1) Vessel 4T 1, 2 4 M SR 3.3.2.1 Equivalent and SR 3.3.2.5 Trip Time Delay $k 3.3.2.9 (a) W ;,J .T- s Vessel aT 4 olm,; [quivalent a 10; Rii to 13.9%

Vessel 4T RTP'"

(Power.1)

(b) -10; Rii - - s Vessel 4T

.s ;;e; .i- Equivalent

!whm" to 23.9%

00; RTF RTP"'

Vessel 6T

) (Power.2)

(4) Containment 1, 2. 3 4 0 SR 3.3.P.1 s 2.0 psig Pressure . SR 3.3.2.5 Environmen'.a1 SR 3.3.2.9 Allowance 4 Hodifier

e. Safety injection Refer to Functinn 1 (Safety Injection) for all initiation furci ons and requirements,

f. Loss of Offsite P wer 1,2,3 2 trains F SR 3.3.2.7 NA SR 3.3.2.9

g. Trip of all Main 1. 2 2 per J SR 3.3.2.8 NA Feedwater Punps pump

h. Auxiliary Fee &ater 1.2.3 3 P SR 3.3.2.1 a 20.64 psia Pump Suction Transfer SR 3.3.2.9 on Suction Pressure . SR 3.3.2.12 Lod (continued)

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

(k) With a time delay 5 240 seconds.

1 With a time delay s 130 seconds, j (n)

() Trip function say te blocked just before sh.itdown of the last operating main feedwater punp and restored just after the first main feedwater pump is put into service follwing performance of its startup trip test.

CALLAWAY PLANT ITS 3.3 37- 5/15/97 i

_________J

l ULNRC-3673 i

l ATTACIIMENT FIVE CIIANGES TO UIRRC-3578 ATl'ACIDIENT 20 E

i R

(

RTS Instrumentation B 3.3.1

• BASES SURVEILLANCE 6. Overtemoerature AT (continued)

REQUIREMENTS for those transients that are slow with respect to delays from the core to the measurement system. The Overtemperature aT trip Function uses each loop's aT as a measure of reactor power and is compared with a setpoint that is automatically varied with the following parameters:

. reactor coolant average temperature the Trip Setpoint is varied to correct for changes in coolant density and specific heat capacity with changes in coolant temperature:

. pressurizer pressure-the Trip Setpoint is varied to correct for changes in system pressure: and

. axial power distribution f(aI) the Trip Setpoint is varied to account for imbalances in the axial #

power distribution as detected by the NIS upper and lower power range detectors. If axial peaks are greater than the design limits, as indicated by the difference between the upper and lower NIS power range detectors, the Trip Setpoint is reduced.

Dynamic compensation is included for system piping delays from the core to the tenperature measurement system.

cl and T h aT. usg in the Overtemperature d 0=ps aT tri .

represent (fthe 100% RTP valu@s measured by the plant for each loop. For the startup of a refueled core until set to actual measured values (at 90100% RTP). AT, is initially assumed at a value which is conservatively lower than the last_ measured 100% RTP aT. for each loop. Setting OV8 "/ * *4"* to the measured valuegwrmalizes each loop'siaT tripdFto the actual operating donditions existing at the time of measurement, thus forcing the trip to reflect the equivalent full power conditions as assumed in the aM $

accident' analyses. hese differences in vessel aT arise due to several factors, the most prevalent being

/

measured RCS loop f ows greater than Minimum Measured Flow, and slightly asymetric power distributions between quadrants. While CS loop flows are not expected to s$ sTo and T' (continued)

CALLAWAY PLANT ITS BASES B 3.3 15 5/15/97

RTS Instrumentation B 3.3.1,

• . - BASES

[ APPLICABLE 6. Overt =marature AT SAFETY ANALYSES, *a /

(continued) T vp LCO, and change with cycle life, (adial power redistribution APPLICABILITY- between quadrants may oc:ur, resulting in small changes in loop specific vessel AT%alues. Accurate determination of the loop specific vessel AT valu(Oruld be made when performing the Incore/Excor quar'trly recalibration and under steady state conditi s (i.e., power distributions not affected by Xe or ot tra 1ent conditions).

a K The time constants utilized in the ik compensation of measured AT, 1 , and measured Tm,t., are set in the field 3

at 0 seconds. This setting corresponds to the 7300 NLL cards used for lag compensation of these signals. Safety analyses that credit overtemperature aT for protection must account for these field adjustable lag cards as well as all other first order lags (i.e., the combined RTD/thernowell' response time and the scoop transport delay and thermal lag). The safety analyses use a total first order lag of less than or equal to 6 seconds.

~The Overtemperature aT trip Function is calculated.for each loop as described in Note 1 of Table 3.3.11. Trip q

-occurs if Overtemperature AT is indicated in two loops, i The pressure and temperature signals are used for other control functions: thus, the actuation logic must be able to withstand an input failure to the control system, which may then require the protection function actuation, and a single failure in the other channels providing the-protection function' actuation. Note that this Function' also provides a signal to generate a turbine runback prior to reaching the Trip Setpoint. A turbine runback will reduce turbine power and reactor power either through automatic rod control or through operation action. A reduction in power will normally alleviate the Overtemperature aT condition and may prevent a reactor trip.

The LCO requires all four channels of the Overtemperature -

aT trip Function to be OPERABLE (two out of four trip logic). Note that the Overtemperature aT Function receives input from channels shared with other RTS Functions. Failures that affect multiple Functions (continued)

CALLAWAY PLANT ITS - BASES B 3.3 16 5/15/97-

RTS Instrumentation B 3.3.1

. BASES

,, APPLICABLE 6. Overtemoerature AT (continued)

SAFETY ANALYSES, LCO, and require entry into the Conditions applicable to all APPLICABILITY affected Functions.

In H0DE 1 or 2, the Overtemperature AT trip must be OPERABLE to prevent DNB. In H00E 3, 4, 5, or 6, this trip Function does not have to be OPERABLE because the reactor is not operating and there is insufficient heat production to be concerned about DNB.

7. 0.veroower aT The Overpower AT trip Function er,sures that protection is provided to ensure the integrity of the fuel (i.e., no fuel pellet melting and less than it cladding strain) under all possible overpower conditions. This trip Function also limits the required range of the Overtemperature aT trip Function and provides a backup to the Power Range Neutron Flux-High Setpoint trip. The Overpower AT trip Function ensures tnat the allowable heat generation rate (kW/ft) of the fuel is not exceeded. The ,

Overpower AT trip also provides protection to mitigate the consequences of small steamline breaks, as reported in Ref. II, and steamline breaks with coincident control rod withdrawal (Ref. 12). It uses the AT of each loop as a measure of reactor power with a setpoint that is automatically varied with the following parameters:

. reactor coolant average temperature-the Trip Setpoint is varied to correct for chanp3 in coolant density and specific heat capacity with cMnges in coolant temperature; and

• rate of change of reactor coolant average tempereiare-including dynamic compensation for the delay, oetween the core and the temperature measurement system.

aT, u he Oxrta.,,=turc =d Overpower AT tri represen he 100% RTP valu@ measured by the plant for each loop. Foa the startup of a refueled core until set to actual measured values (at 90100% RTP). aT, is (continued)

CALLAWAY PLANT ITS BASES B 3.3 17 5/15/97

RTS Instrumentation B 3.3.1 1 BASES APPLICABLE 7. Overoower AT n

. SAFETY ANALYSES, (continued)

( Od$*MI @*

LCO, and initially assumed at a value which is conserva ively lower APPLICABIL:TY than the last measurec 100% RTP AT, for each oop. Se(ting to the measured valueinormalizes each loop's aT tripdrto the actual operating conditions existing at the time of measurement, thus forcing the trip to reflect the equivalent full power conditions as assumed in the accident analyses. These differences in vessel aT ed T) arise due to several factors, the most prevalent being measured RCS loop flows greater than Minimum Heasured Flow, and slightly asymmetric power distributions between quadrants. While RCS loop flows are not expected to change with cycle life, radial power redistribution between quadrants may occur, resulting in small changes in loop specific vessel aT values, curate determination of the loop specific vesse a val uld be made when performing the Incore/ cor quarterly recalibration and under steady state co itic s (i.e., power distributions not affected by Xe or the(transientegnditions).

W Tv The time constants utilized in the lag compedation of measured AT. 3t . and measured Tm,T., are set in the field at 0 seconds. This setting corresponds to the 7300 NLL cards used for lag compensation of these signals. Safety analyses that credit Overpower aT for protection must account for these field adjustable lag cards as well as all other first order lags (i.e., the combined RTD/

thermowell response time and the scoop transport delay and thermal lag). The safety analyses use a total first order lag of less than or equal to 6 seconds.

The Overpower AT trip Function is calculated for each loop as per Note 2 of Table 3.3.11. Trip occurs if Overpower aT is indicated in two loops. The actuation logic must be able to withstand an input failure to the control system, which may then require the protection function actuation and a single failure in the remaining channels providing the protection function actuation. Note that this Function also provides a signal to generate a turbine runback prior to reaching the Trip Setpoint. A turbine runback will redece turbine power and reactor power. A reduction in power will normally alleviate the Overpower AT condition and may prevent a reactor trip.

(continued)

CALLAWAY PLANT ITS BASES B 3.3 18 5/15/97

RTS Instrumentation B 3.3.1

. I BASES APPLICABLE 14. Steam Generator Water level Low low (continued) 3,4/ sg SAFETY ANALYSES, LCO, and performs the ESFAS function of starting the AFW p ps on APPLICABILITY low low SG 1evel. As discussed in Reference 7, 1 he SG Water Level Low Low trip function at Callaway ias been modified to allow a lower Trip Setpoint under al containment environmental conditions and a dela ed trip when THERMAL POWER is less than or equal to TP. This circuitry reduces the potential for inadvertent trips via  ;

the Environmental Allowance Modifier (EAM), dependent on containment pressure, and the Trip Time Delay (TTD),

dependent on vessel AT (THERMAL POWER), With the transmitters (d/p cells) located inside containment and thus possibly experiencing adverse environmental conditions (due to a feedline break), the Environmental Allowance Hodifier (EAM) vas devised. The EAM function senses the presence of adverse containment conditions (elevateo pressure) and enables the Steam Generator Water Level - Low Low trip setpoint (Adverse) which reflects the increased transmitter uncertainties due to this environment. The EAM allows the use of a lower Steam Low Low trip setpoint (Normal)

_7 k

Generator Water Level when these conditions are not present, thus allowing more margin to trip for normal operating conditions. The Trip Time Delay (TTD) creates additional operational margin when the plant needs it most, during early escalation to power, by allowing the operator time to recover level when the primary side load is sufficiently small to allow sucn action. The TTD is based on the continuous monitoring of primary side power through the use of Vessel aT. Scaling of the Vessel AT channels is dependent on the loop-specific values for AT , discussed under the OTDT and OPDT trips. Two time delays are possible, based on the primary side power level, the magnitude of the trip delay decreasing with increasing powe- In the event that the EAM or TTD functions do not meet the required channels, it is acceptable to place the inoperable channels in the tripped condition and continue operation. Placing the inoperable channels in this mode will result in the enabling of the Steam Generator Water Level Low Low (Adverse) function, for the EAH, or in the removal of the trip delay, for the TTD. In the event that the Steam Generator Water Level Low Low (Normal) function does not (continued)

CALLAWAY PLANT ITS BASES B 3.3 25 5/15/97 3

,.n.

RTS Instrumentation B 3.3.1

• BASES

[' .

APPLICABLE SAFETY ANALYSES, 14, Steam Generator Water level Low Low (continued)

LCO, and meet the required channels, the channels can be tripped or APPLICABILITY it is acceptable to place the associated EAM channels in the tripped condition and continue operation. Performing the latter action is preferred since a partial trip is i avoided; however, this will result in the enabling of the Steam Generator Water Level Low Low (Adverse) function which has a more conservative (higher level) trip setpoint. At this time it would also be acceptable to place the inoperable Steam Generator Water Level Low Low (Normal) channels in the bypassed condition to prevent an inadvertent Reactor Trip or ESFAS actuation.

The LCO requires four channels of SG Water Level-Low Low per SG to be OPERABLE because these channels are shared between protection and control. All SG Water Level-Low Low reactor trip Functions use two out of four logic.

As with other protection functions, the single failure criterion applies. The Trip Setpoints for the SG Water Level Low Low (Adverse Containment Environment) and (Normal Containment Environment) bistables are a 20.2% and a 14.8% of narrow range span, respectively. The Tri g ,g Setpoints for the Vessel aT (Power 1) and (P -

bistables are s Vessel AT Equivalent to TP and s Vessel aT Equivalent to RTP, respectively, with corresponding trip time delay of s 232 seconds and s 122 seconds. The Trip Setpoint or the_ Containment Pressure - 3' Environmental Allowance Hod' ier bistables is s 1.5 psig.

2 2.41 %

In H00E 1 or 2, when the reactor requires a heat sink, the SG Water Level-Low Low trip must be OPERABLE. The normal source of water for the SGs is provided by the Main Feedvater (MFW) Pumps (not safety related). The MFW Pumps are only in operation in MODE 1 or 2. The AFW System is the safety related source of water to ensure that the SGs remain the heat sink for the reactor. During normal startups and shutdowns the HFW System or AFW System provides fedwater to maintain SG level. In MODE 3, 4, 5, or 6, the SG Water Level-Low Low Reactor Trip Function does not have to be OPERABLE because the reactor is not operating or even critical (see Specification 3.3.2 for Applicability of SG Water Level Low Low ESFAS Functions).

(continued)

CALLAWAY PLA E ITS BASES B 3.3 26 5/15/97

,;.-s,7 RTS Instrtmentation B 3.3.1

• -BASES-b* SURVEILLANCE SR 3.3.1.4 (continued)

( . REQUIREMENTS-The Frequency of every 31 days on a STAGGERED TEST BASIS is adequate. It is based on industry operating experience, considering.instnment reliability and operatirg history data.

SR 3.3.1.5 SR 3.3.1.5 is the performance of an ACTUATION LOGIC TEST. The SSPS is tested every 31 days on a STAGGERED TEST BASIS, using the semiautomatic tester. The train being tested is placed in the bypass condition,' thus preventing inadvertent actuation. Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function, including operation of the P 7 permissive which is a logic ' unction only. The Frequency of every 31 days on a STAGGERED TEST BASIS is adequate. It is based on industry operating experience, considering instrument reliability and operating history data.

SR 3.3.1.6

-SR 3.3.1.6 is a calibration of the excore channels to the incore -

channels. If the measurements do not _ agree, the excore. channels are not declared inoperable but must be calibrated to agree _with the incore detector measurements. If the excore channels cannot be adjusted, the channels are declared inoperable. This Surveillance is performed to verify the f(aI) input to the Overtemperature AT Function. Determination of the loop specific vessel aT val @ld be made when performing this calibration.

under( and stefdy

%g. -state conditions-(aT,(when en) W [T" at 100% RTP A Note modifies SR T.3.1.6. The Note states that this Surveillance is required only if reactor _ pour is a 75% RTP and-that 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after achieving equilibrium conditions with THERMAL POWER a 75% RTP is allowed for performing the first surveillance.

The Frequency of 92 EFPD is adequate. It is based on industry operating experience, considering instrument reliability and operating history data for instrument drift.

(continued)

CALLAWAY PLANT ITS BASES B 3'.3 54 5/15/97

Table B 3.3.1 1 (Page 2 of 3)

FUNCTION TRIP SETPOINT 3

3 , 14. Steam Generator (SG) Water Level Low Low 9

a. Steam Generator Water Level a 20.2% of narrow range Low Low (Adverse instrument span Containment Envirorment)

b. Steam Generator Water Level a 14.8% of narrow range Low Low (Normal Containment instrument span Environment)

c. Vessel AT Equivalent and Trip Time Delay

,gf, (1) Vessel AT Equivalent s Vessel oT Equivalent to s TP Vessel AT 4 W3 RTP (with a time delay (P r 1,) /a 4/ s/, s 232 sec.)

(2) -tet%TP < Vessel aT s Vessel oT Equivalent to Equivalent s Get RTP -G M 3 RTP (with a time delay Vessel AT (Powe 2) ."Ja.4/ 8/, s 122 sec.)

d. Containment Pressure 33 f/% s 1.5 psig Environmental Allowance Modifier

15. Not Used.

16. Turbine Trip

a. Low Fluid Oil Pressure a 598.94 psig

b. Turbine Stop Valve Closure a 1% open

17. Safety Injection (SI) Input from N.A.

Engineered Safety Feature Actuation System (ESFAS)

18. Reactor Trip System Interlocks

a. Intermediate Range Neutron a 1.0E 10 amps Flux. P 6

b. Low Power Reactor Trips N.A.

Block, P 7 (continued)

CALLAWAY PLANT ITS - BASES B 3.3 63 5/15/97

m '

ESFAS Instrumentation B 3.3.2

. BASES

• d. Auxiliary Feedwater Steam Generator Water Level -

APPLICABLE SAFETY ANALYSES, Low Low (continued)

LCO, and APPLICABILITY required to satisfy the requirements with two out of four logic (the EAM and TTD functions also use a two out of four logic). Two out of four low level signals in any SG starts the motor driven AFW pumps, in two SGs starts the turbine driven AFW pump. As discussed in Reference 11, the SG Water Level Low Low trip function at Callaway has been modified to allow a lower Trip Setpoint under normal containment environmental conditions and a delayed trip when THERMAL POWER is less than or equal toget-RTP.

pp 4/M This circuitry reduces the potential for inadvertent trips via the Environmental Allowance Modifier (EAM), dependent on containment pressure, and the Trip Time Delay (TTD), dependent on vessel AT (THERMAL POWER). With the transmitters (d/p cells) located inside containment and thus possibly experiencing adverse environmental conditions (due

) to a feedline break), the Environmental Allowance Modifier (EAM) was devised. The EAM function senses the presence of adverse containment conditions (elevated pressure) and enables the Steam Generator Water Level Low Low trip setpoint (Adverse) which reflects the increased transmitter uncertainties due to this environment. The EAM allows the use of a lower Steam Generator Water Level Los Low trip setpoint (Normal) when these conditions are not present, thus allowing more margin to trip for

~

normal operating conditions. The Trip Time Delay (TTD) creates additional operational margin when the plant needs it most, during early escalation to power, by allowing the operator time to recover level when the primary side load is sufficiently small to allow such action. The TTD is based on the continuous monitoring of primary side power through the use of Vessel aY. Scaling of the Vessel aT channels is dependent on the loop specific values for AT,, discussed under the OTDT and OPDT trips.

Two time delays are possible, based on the primary

) (continued)

BASES B 3.3 93 5/15/97 f CALLAWAY PLANT ITS l

st.v> 5 ESFAS Instrumentation.

B 3.3.2 o BASES N -APPLICABLE d. Auxiliary Feedwater Steam Generator Water Level -

\ SAFETY ANALYSES. Low Low (continued)

LCO, and APPLICABILITY side power level, the magnitude of the trip delay decreasing with increasing pmer. In the event tnat the EAM or TTD functions do not meet the required channels, it is acceptable to place the inoperable channels in the tripped condition and continue operation. Placing the inoperable channels in this mode will result in the enabling of the Steam Generator Water Level Low Low (Adverse) function, for the EAM, or in the removal of the trip delay, for the TTD. In the event that the Steam Generator Water Level Low Low (Normal) function does not meet the required channels, the channels can be tripped or it is acceptable to place the associated EAM channels in the tripped condition and continue operation. Performing the latter action is preferred since a partial trip is avoided; however, this will result in the enabling of the Steam Generator Water Level -Low Low (Adverse) function which has a more conservative (higher level) trip setpoint. At this time it would also be acceptable to place the inoperable Steam Generator Water Level Low Low (Nomal) channels in the bypassed condition to prevent an inadvertent Reactor Trip or ESFAS actuation.

The Trip Setpoint _reficcts the inclusion of both steady state and adverse environment instrument uncertainties. The Trip Setpoints for the SG Water Level Low Low (Adverse Containment-Environment) and (Normal Containment Environment) bistables are -

a 20.2% and a 14.8% o ' narrow range span, respectively. The Trt,; Setpoints for the Vessel aT (Power 1) and (Power 2) bistables are s Vessel AT Equivalent toMRTP and s Vessel AT Equivalent to 22 W8/, e # RTP respect rely, with corresponding trip time delays of s 232 econds and s 122 seconds. The Trip Setpoint f the Containment Pressure -

C Environmental Al owance Modifier bistables is s 1.5 psig, j

' /2.f/*/,

(continued)

CALLAWAY PLANT ITS BASES B 3.3 94 5/15/97

.. t .;*-

-Table B 3.3.2 1 (Page 3 of 4)

FUNCTION TRIP SETPOINT

6. Auxiliary Fee & ster (continued)

, d. SG Water Level Low Low (1) Steam Generator a 20.2% of narrow range Water Level Low Low instrument span (Adverse Containment Environment)

(2) Steam Generator a 14.8% of narrow range Water Level Low Low instrument span (Normal Containment Environment)

(3) Vessel AT Equivalent and Trip Time Delay e /2.41*/,

(a) Vessel aT s Vessel aT Equivalent Equiva lent to TP (with a time s tW RTP de y s 232 sec.)

Vessel AT (Power 1) gj, ,

/2.4/ */,

(b) M TP < s Vessel aT Equivalent Vessel aT to B M RTP (with a time Equivalent del y s 122 sec.)

s RTP Vess aT 22 * +/ #d (P 2) 3 3.41%

(4) Containment Pressure s 1.5 psig Environmental Allowance Modifier

e. Safety Injection See Function 1 (Safety Injection).

f. Loss of Offsite Power N.A.

g. Trip of all Main Feedwater N.A.

Pumps

h. Auxiliary Feedwater Ptap = 21.71 psia Suction Transfer on Suction Pressure Low (continued)

CALLAWAY PLANT ITS BASES B 3.3 125 5/15/97

. . .