ML20094N407

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Proposed Tech Specs,Converting Existing TS to Format & Content of NUREG-1431
ML20094N407
Person / Time
Site: Vogtle  Southern Nuclear icon.png
Issue date: 11/20/1995
From:
GEORGIA POWER CO.
To:
Shared Package
ML20094N384 List:
References
RTR-NUREG-1431 NUDOCS 9511280030
Download: ML20094N407 (31)
v • d • e


Text

._

P TABLE 4.3-1 (Continued) Q-

% REACTOR TRIP SYSTEN INSTRUNENTATION SURVEILLANCE REQUIRENENTS (

TRIP E 51 :=0; ACTUATING NODES FOR 53 Q CHANNEL DEVICE WHICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE llESf0N6E TEST TEST LOGIC TEST IS REQUIRED n tn e. TEST 1 FUNCTI%AL UNIT CllECK_

sx3 3.t.1 CALIBRATION S R 3. 3.t . lb SR 3.3,l 7 4- -#- N.A. N.A. I' , 2' l SR311.15

[ 13. Steam Generator Water Level-- -S-Low-tow

  • 00P1 LOOP 2 LOOP 3 LI-0537 LOOP 4 LI-0547 4ggg3 LI-0517 LI-0527 LI-0518 LI-0528 L1-0538 LI-0548 LI-0519 LI-0529 LI-0539 LI-0549 LI-0551 LI-0552 LI-0553 LI-0554) -

a s.3.l.lo ena.3.1R @ N.A. s R 3,s.,.; g 3

$ 14. Undervoltage - Reactor Coolant N.A. -R- N.A. + l' l Pumps i' sg3.3.I.10 3 R 3 3.13 U DO'

  • C 15. Underfrequency - Reactor N.A. -R- N.A. -Q- N.A. l' l Coolant Pumps
16. Turbine Trip SR3.3.1.1O Ftt7,3.f./6 4";/4, !O)h N N.A. l' ' l gg gg a. Low Fluid Oil Pressure - N.A. -R-

,e,

  • Wb. EPT-6161, PT-6162, PT-6163)) sR3 3.1.io 3.A.

- $3 S/"'!, l* 3k10) N.A. Ib p

urbine Stop Valve closure N. A. 4- N.A.

E 17. Safety Injection Input from N.A. N.A. N.A. N.A. 1, 2 gg ESF

18. Reactor Trip System Interlocks

$$ a. Intermediate Range R 3'3'I II ERB 3' hlb Neutron Flux P-6 N.A. $l ftt+) 4- N.A. N.A. 2* ' l kA

-- (NI-00358,D& ,

$$ NI-00368,D&G)

N A ffU 6** k '* ** E 3 'r" Y F ' ""; # h " 'd **

  • f
  • pecification BA3ES cv:d prior to JLYceecLog Me P-f m/ertak trof sefpa'sof;

~~

9511200030 951120

. PDR ADOCK 05000424 E-.~,_ .._._ _PDR _ _

a

.p T'

= R

-TA::lI ".0-2 l L.M.. . i-ENGINEERED SAFETY FEATURES ACTUATION SYSTEN INSTRUMENTATION O] q g SURVEILLANCE REQUIRENENTS y (

E TRIP h.3.2.Q 33 1 p MWM ANALOG CHANNEL ACTUATING DEVICE T,md Te# MASTER SLAVE NODES FOR lellCH g "P+

CHANNEL CHANNEL CHECK CALIBRATION TEST DPERATIONAL OPERATIONAL AC-ftfAff0Nr TEST t0Gif-ff3t RELAY TEST RELAY SURVEILLANCE

] p g(

q

[ FUNCTIONAL UNIT TEST IS REOUIRED. (p ps

c. 10. Control Room Emergency Filtration LCO 3,3,7 7'B6LE 3,3,7-/ O' %

System Actuation (Continued) O

c. Safety Injection
d. Intake Radiogas sR3 3,7,1 See Functional Unit 1. above for all Safety Injection Surveillance Requirements.

3R 3,3,7,2 ~'i,3.2 2. Either Unit-le-h3M m

Q Monitor 5 A 3,3.7.5~

4- 4t-Q 18 N.A. 4h*:

sg 3,3,7 (>

N.A. M.A. 1, 2, 3 ge, ya , 4, (w

e m3

> (RE-12Il6,RE-12117) uw So2 na Ac d  !! n c tion h Nor IMRTcF Ldo 3,J,7 k5ee WAS Mf mg (Common System)

a. Manual Initiation N.A. N.A. N.A. R N.A. N.A. M.A. (2) y{'N
b. Fuel Handling S R N N.A. N.A. M.A. N.A. (2)

, Building Exhaust

(( Duct Radiation

== Signal 0"

([ (ARE-2532 A&B D gg ARE-2533 A&B) gg c. Automatic M.A. N.A. N.A. N.A. N(1) N.A. N.A. (2) m Actuation Logic gg and Actuation pi Relays 31 TABLE NDTATION

((

ee (1) au Each train, sha,l,l be,- - _test,ed,_at _

least every Mdays on a STAGGTEST BASIS. ) sR3.3.7.3 yq

' - as ~ . ---- --- ~ gg 3,3 Sc During moNt ofi$dlated fuei ['- EEE- tYi51.... . S tM fsM ADD M E M 4 N S W'

    1. This function may be bypassed for survelliance testing provided that the appilcable Action Statement requirements II N re met. NOTPART of LOO 3,3,7 (see ESMS W6ffup)

i o

r' Ch O am b (O TABLE 4.3-2 (Continued) .

NV ta ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION g SURVEILLANCE REQUIREMENTS gh M TRIP h 4. 3.~2 . E Ob $ Ul CS

"' ANALOG ACTUATING ;2ESRW5E MODES FOR WHICH 3-q E CHANNEL DEVICE DmE TEs7 MASTER SLAVE ' 'T]

OPERATIONAL OPERATIONAL--AcfUAfteN RELAY RELAY SURVEILLANCE Z CHANNEL CHANNEL

' '*!C !EST- TEST IS REQUIRED

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST __ IESJ_

6. illary Feedwater

[

a. Automa tuation M.A. N.A N.A. M.A. M(1) M(1) Q , ,3 V

hm NOTPPRrof ILO 3,3,5-(see ESFAS s

narnn b

@ b. Steam Generator Water 'y y Level-Low-Low

$ w LI-0517 LI-0518 LI-0527 LI-0528 L!-0537 LI-0538 LI-054 LI- l LI-0519 LI-0529 LI-0539 -0549 i 1 LI-0554)

I

- LI-0551 LI-0552 LI-0551

1) Start Motor-Driven Pumps R Q N.A. N.A. . N.A Iff,2ff,3ffl
2) Start Turbine- riven M.A. M.A. N.A N.A #f,2ff,3ffl P S R Q

((

gg c.

Motor-Driven Pumps ty injection Start See Functional Unit 1. above for all Safety Injection Surveillance Requirement . h<

gg d. Loss of or Degraded M.A. -R- Q sA3.38 l N.A. -*:*: D SR 3,3,5,3 N. A. N.A 1, 2, 3

'l d b

4.16 kV ESF Bus Voltage sR.3.3.5.1

$;f.i of All Main feed- N.A. N.A. M.A. R N.A. N.A. N.A 1 Matet n

  • g p py of g o3,3,5~_._ x " ,_L_

g,gpg5 Agg)ruf Notor-Driven Pumps _

f. Manual Initiation M.A. N.A. N.A. M.A. N.A. 1, 2, 3 gg .

OO

_ *m L 3.6

_ . _ _ _ . _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . - - _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ . _ _ _ - _ - _ _ _ . _ _ _ _ _ __m_ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ . _ _ _ _ _ __,______________m_____ _ _ _ _ _ _ _ - _ ._.______._________._.____m___

, .l

% \

D 5  !

?*

TABLE 4.3-2 (Continued) oH 8 g ,

E ENGINEERED SAFETY FEATURES ACTUATION SYSTEN INSTRtNIENTATION 00 g g SURVEILLANCE REQUIRENENTS Q '

n TRIP (*l.3.2,1)

. ANALOG ACTUATING m NODES FOR WHICH (11 CA -i

- CHANNEL DEVICE -rsmE 7EST- NASTER SLAVE

, CHANNEL CHANNEL OPERATIONAL OPERAll0NAL -AETUAHON RELAY RELAY SURVEILLANCE N m FUNCTIONAL UNIT CHECK E8LLBRATION TEST TEST 496K-YEST TEST TEST IS REQUIRED 00 S*'&*Q' @ NarPART o F LLO 3,3,5 (see ESFAS "'**P) 5 b

rr) a. Automatic Actuation .. .A. N.A. N.A. M(1 (1) Q 1, 2, 3, 4 6 Logic and Actuation (A

@ Relays (p g

  1. b. RWST Level-Low-tow
  • 5 R N.A. .A. N.A. M.A 1", 2", 3", 4" r* Coincident With Safety D r

] Injection

-0991A&8, g  !

(LI-09 ,

A,LI-0993A)

8. Loss of Power to $ 7

[

4.16 kV ESF Bus Q h ,,..m v . ~. -

"^-

(l D

= a. 4.16 kV ESF Bus N.A. -R- -M- N.A. N.A. M.A. 1, 2, 3, 4

[ Undervoltage-Loss SRs.F.52. se s.3.M s t of Voltage /Y

.o o b. 4.16 kV ESF Bus M.A. -4t- -M- M.A.

M.A. N.A. 1, 2, 3, 4 g Undervoltage- se,355.7. SR3 35 / 4". 3. Z , .,. q

$;O Degraded Voltage d

??  %

33 -o-UC

  • See Specification 4.3.3.6

-O i

1 I

The following pages replace and supplement the existing pages behind the Enclosure 2 tab for Chapter 3.3, Volume 3.

1 l

l 1

i

VEGP ITS Conversion'  !

Enclosure 2 - Discussion of Changes Chapter 3.3 -Instrumentation j 3/4.3.1 RTS INSTRUMENTATION  :

I CHANGE '

NUMBER SHE DISCUSSION I

< required Channel Calibration is adequate to ensure the setpoint  !

remains within the required tolerance. This change is considered j i less restrictive for VEGP but is consistent with NUREG-1431. l 50 A The Notes affecting the Turbine Trip functions are incorporated )

into VEGP ITS SRs 3.3.1.14 and 3.3.1.16 and their associated -

frequencies, consistent with NUREG-1431. In addition, the

~

frequency for the low fluid oil pressure turbine trip function is revised to be consistent with the applicability for this function  ;

j 4

(above P-9 or 50 % RTP). The TS require that surveillances be i performed prior to the Mode of Applicability. The current TS  :

frequency of this surveillance "S/U" (meaning reactor startup) does  :

not clearly state the performance requirement for a function with  :

7' an applicability of above 50% RTP. Therefore, the frequency of the corresponding VEGP ITS SR 3.3.1.16 is revised to "After each 3- Mode 3 entry for unit shutdown and prior to exceeding the P-9  !

i interlock trip setpoint." This revision is intended as a clarification and is consistent with the intent of the original surveillance '

frequency and with the Applicability of the instrument function L (above P-9). Therefore the revision of this frequency is considered an administrative change.

I~ 51' A The VTS Note 4 to exclude neutron detectors from the Channel  !

Calibration is incorporated into the ITS SR 3.3.1.11. This change is considered administrative and is consistent with NUREG-1431.

52 A The VTS Note 7 that modifies the frequency of the applicable ,

surveillances, is incorporated into the frequency for ITS SR 3.3.1.4 and SR 3.3.1.5. In addition, since the definition of Staggered Test .

Basis has been revised the test frequency is now stated as 31 days on a staggered test basis instead of 62 days on a staggered test l basis. The actual test frequency for a given channel is not .

changed. Only the definition of staggered test basis has changed. 1

. This change is considered administrative and is consistent with

NUREG-1431.

f

~

e 17-Chapter 3.3 - E2-M ' October 5,1995 1 l

, s .,s

i VEGP ITS Conversion l Enclosure 2 - Discussion of Changes Chapter 3.3 - Instrumentation 3/4.3.1 RTS INSTRUMENTATION CHANGE NUMBER SJJE DISCUSSION 53 LG Note 11 that provides descriptive information regarding the content of the required test is moved into the Bases discussion for the corresponding ITS TADOT SR 3.3.1.4. This change is less restrictive due to the Bases being controlled by the licensee under the Bases Control Program in the Administrative Controls Section of the ITS. This change is consistent with NUREG-1431. -

54 LG Notes 15 and 16 that provide descriptive information regarding the  ;

content of the required test are moved to the bases for the applicable ITS SR. This change is less restrictive due to the Bases being controlled by the licensee under the Bases Control Program in the Administrative Controls Section of the ITS. This change is consistent with NUREG-1431.

55 A A separate line item for the undervoltage and shunt trip mechanisms is provided in the ITS. The separation of these functions facilitates IE

- Chapter 3.3 E2-19 October 5,1995

l VEGP ITS Convcrsion Enclosure 2 - Discussion of Changes i Chapter 3.3 - Instrumentation i

3/4.3.3 MONITORING INSTRUMENTATION ,

RADIATION MONITORING FOR PLANT OPERATIONS AND  !

I APPLICABLE ESFAS PAGES FOR NEW NUREG-1431 LCOS CONTAINMENT VENTILATION ISOLATION AND . l CONTROL ROOM EMERGENCY FILTRATION ,

CHA'NGE  ;

NUMBER S13E  :

with the requirements of the NUREG-1431 LCO that now contains the setpoints.  ;

32 Not used. ,

33 A A specific SR is identified for Response Time Testing of the Control l Room Emergency Filtration Function. This addition of a specific surveillance requirement for Response Time Testing is consistent with NUREG-1431 as the generic surveillance requirement of the current ESFAS TS for Response Time Testing is not used in the NUREG-1431 format. Each instrument function has the required surveillances  ;

identified. j i

r r

i l

50 Chapter 3.3 E2-X October 5,1995 i

~

VEGP ITS Conversion .

Enclosure 2 - Discussion of Changes f Chapter 3.3 -Instrumentation  ;

1 APPLICABLE ESFAS PAGES FOR l THE NEW NUREG-1431 LCO 3.3.5 }

ESF BUS LOSS OF POWER (LOP) INSTRUMENTATION CIIANGE  :

N. UMBER SiiE j At VEGP the loss of power instrument channels are similar to the l protection channels used in the ESFAS and RTS, in that a processed  ;

signal from a sensor is used to trip an output bistable that inputs a l signal to actuation logic and relays. Similar instrument channels in  :

the ESFAS and RTS currently have quarterly ACOT requirements that [

have proven adequate, based on operating experience, to ensure l operability. Furthermore, the sensors for the loss of power channels are potential transformers (not uv relays) and have no moving parts. ,

The potential transformers are inherently more reliable than the  ;

pressure transmitters typically used in RTS and ESFAS instrument channels. The loss of power instrumentation channels at VEGP are at least as reliable as similar channels in the ESFAS and RTS that are {

tested quarterly. Therefore,'a quarterly ACOT on the loss of power [

instrument channels is adequate to ensure their operability. 1

.. 13 A A specific SR is identified for Response Time Testing of the AFW system initiation on the LOP Functions. This addition of a specific surveillance requirement for Response Time Testing is consistent with ,

NUREG-1431 as the generic surveillance requirement of the current '

i ESFAS TS for Response Time Testing is not used in the NUREG-1431 format. Each instrument function has the required surveillances identified.

14 LS23 The requirement to perform specific response time testing of the Loss of Power (LOP) instrumentation Diesel Generator start is deleted .

I consistent with NUREG-1431 as modified by NRC-22 change package and marked-up on page 3/4 3-42 in Enc 1. The requirement for this testing is redundant to the response time tests performed for the ESF  ;

equipment including the Emergency Diesels (in LCO 3.8.1) and i Auxiliary Feedwater pumps (SR 3.3.5.3) and the Channel Operational Tests'and Channel Calibrations performed on the LOP instrumentation to verify the correct time delays and sensor operation. Note that the  ;

ESFAS surveillance requirement (4.3.2.2) for response time testing of the AFW system for LOP initiation is retained as SR 3.3.5.3 as marked P

5 .

Chapter 3.3 E2-6/ October 5,1995 i

Q VEGP ITS Conversion Enclosure 2 - Discussion of Changes

. Chapter 3.3 - Instrumentation APPLICABLE ESFAS PAGES FOR THE NEW NUREG-1431 LCO 3.3.5 ESF BUS LOSS OF POWER (LOP) INSTRUMENTATION CIIANGE NUMBER SJJE on page 3/4 3-41 in Enc 1. The LOP response time SR for the AFW system initiation is retained consistent with the verification of the VEGP safety analyses assumptions for AFW system initiation with and without offsite power.

So Chapter 3.3 E2-6/ October 5,1995

1 I

l The following pages replace the corresponding pages behind the  :

Enclosure 3 tab for Chapter 3.3, Volume 3.

VEGP ITS Conversion Enclosure 3 - Significant Hazards Evaluations Chapter 3.3 - Instrumentation IV. SPECIFIC SIGNIFICANT HAZARDS EVALUATIONS ~

LCO 3.3.5 ESF BUS LOSS OF POWER (LOP) INSTRUMENTATION "LS23" The requirement to perform specific response time testing of the Loss of Power (LOP) instrumentation Diesel Generator start is deleted consistent with NUREG-1431 as modified by NRC-22 change package and marked-up on page 3/4 3-42 in Enc 1. The requirement for this testing is redundant to the response time tests performed for the ESF equipment including the Emergency Diesels (in LCO 3.8.1) and Auxiliary Feedwater pumps (SR 3.3.5.3) and the Channel Operational Tests and Channel Calibrations performed on the LOP instrumentation to verify the correct time delays and sensor operation. Note that the ESFAS surveillance requirement (4.3.2.2) for response time testing of the AFW system for LOP initiation is retained as SR 3.3.5.3

. as marked on page 3/4 3-41 in Enc 1. The LOP response time SR for the AFW system initiation

' is retained consistent with the verification of the VEGP safety analyses assumptions foi AFW system initiation with and without offsite power.

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

The proposed change involves changing the TS surveillance requirements for the ESF Bus Loss of Power Instrumentation to more closely agree with the Westinghouse Standard ITS (NUREG-1431) and does not result in any hardware changes. The Loss of Power Instrumentation is not assumed to be an initiator of any analyzed event. The role of the Loss of Power Instrumentation is to monitor and ensure an adequate voltage is maintained on the ESF Busses as well as providing an anticipatory start of the Auxiliary Feedwater Pumps. The proposed change still ensures the Loss of Power instrumentation remains capable of providing the required monitoring and actuation functions as described in the FSAR and that the results of the analyses in the FSAR remain bounding.

Additionally, the proposed change does not impose any new safety analyses limits or t alter the plants ability to detect and mitigate events. Therefore, this change does not  !

involve a significant increase in the probability or consequences of an accident previously

2. Does the change create the possibility of a new or different kind of accident from any ,

accident previously evaluated?  !

The proposed change involves changing the TS requirements for the Loss of Power Instumentation to more closely agree with the Westinghouse Standard ITS (NUREG-

' 1431) requirements and does not necessitate a physical alteration of the plant (no new or ,

different type of equipment will be installed) or changes in parameters governing normal l plant operation. Thus, this change does not create the possibility of a new or different kind of accident from any accident previously evaluated.

3 Chapter 3.3 E3-6/ - October 5,1995

~

, i o i VEGP ITS Conversion  !'

Enclosure 3 - Significant Ilazards Evaluations Chapter 3.3 - Instrumentation j l

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

The proposed change, which revises the TS requirements for the Loss of Power l Instrumentation to be consistent with the Westinghouse Standard ITS (NUREG-1431) _ j '

requirements does not involve a significant reduction in a margin of safety. The proposed change still requires the Loss of Power Instrumentation to be operable and ensures the -

monitoring and actuation capability of the instrumentation is available when necessary to +

assist in the mitigation of accidents. In addition, the proposed change eliminates  !

duplicative testing requirements. As such, any reduction in the margin of safety is -l insignificant and will likely be offset by the benefit gained through the improved use of

  • utility resources.  ;

i l

1 NW

l O

The following pages replace the corresponding pages behind the Enclosure 4a tab for Chapter 3.3, Volume 3.

)

, 1

'~

o RTS Instrumentation  :

3.3.1 i .

l SURVEILLANCE REQUIREMENTS (continued) i SURVEILLANCE FREQUENCY 13 SR 3.3.1./ -------------------NOTE--------------------

h $_ _ $ $"_$__I$b!!!"b f!_$ !__I_$ _Ib__

J Perform TADOT. 1 months

/V /

< mr SR 3.3.1.PI 4-------------------NOTE-------------- - - / -----NOTE------

l

' 2. Verification of setpoint is not requirei ! ipnly required

________________________________________.- when not i performed -

within previous 31 da

, ( _____ys__________)  ;

4 Perform TADOT. Prior to

reactor startup 15 l SR g 3. 3.1./ -------------------NOTE--------------------

[

4 Neutron detectors are excluded from respon.ie time testing, ,

} Verify RTS RESPONSE TIME is within limits. 18 months on

a STAGGERED 1 TEST BASIS i

i b

s g a , s. t . i s . . . . . . . . - - - - - - - - - -

L 1, poly re7 & recL when notperkunec s.

l '

2R w,Wo pevlovs 3icla 2, nr;ks,en of seff oiohs *$

re ____ Mter eu.hmth MODE 3 e%

4

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w um+ nout

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Per or m O D I- the P-9 interlak g

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frip se+ pot

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,NOV-06-1995 12:19 FROM UDGTLE TECH. SUPPORT ,

TO 9C OG/LIC P.05 1

! ESFAS Instrumentation 3.3.2 1

1 l j

tehte 3.3.2 1 (sese & of 8)

Engineered safety Feature actuatiam eyesen lastnmentation 1

j

}: APPLICAsLE -

uness sa e i Must stCIFlu ageltup ALLam0LE TRIP 4 Flatflu camifles CateuIELS Cemifles genflammfft MLUE SEfpetiff i

f, . ic Settehever

t. 4, nt m.,

l (cent -

l

c. ausi Lovet 4 1,2,3,4 4 K a 3.3.2.1 35 1 Lou a (1513 a 3.3.2. ,

M '

J.2.10 l

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teinsteret with sofer to Fe stien 1 ( estion) for e4L Initletten Safetyinjestien fe rtiene e d .

i W i

I Coinciden 1,2,3,4 4 g at 3.3.2.1 in.

i $) Cent simp sa 3.3.2.5 t t t3 in.

eksve -

i 6 -esen at 3.3.1.9 et. (Full f t t 2ft w

SE 3.3.2.10

8. ESPAS Intertasks (- s

! e. Reester Trfy, P-4 1,2,3 ' T Al 3

1 trek t at 3.3.2.ff.9 h4 RA

traine
k. Pressuriser 1,2,3 3

% 2010 d -

L 3 440365 g M poig

, Prosaure, P 11 se 3.3.2 pels a 3.3.2 3

c. T -tau , r

... 50.61*F t (5533'F t 52 3.3. 9

' [3] per n se 5 (52.631 Level -etch Nigh, -

.3.2.5 l P 14 1 ,

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, ] ; ,'[,2

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, WOG STS 3.3-36 Rev. O, 09/28/92 i

,NOV-06-1995 12:18 FROM UDGTLE TECH. SUPPORT TO SNC ENG/LIC P.02

. LOP Ofr46ert Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS (continued) i

SURVEILLANCE FREQUDICY l .

SR 3.3.5./ Perform CHANNEL CALIBRATION.; C '_2;_;... I nths nr: :n' x ::" = . '

e l

i i _

! a. Loss of voltage Allowable Value i

k (2912) V with a time delay of i .8) c [ t seconds  ;
Los f voltage Trip Se int k(297 Y with a-ti delay of f[

{ (0.8) secon MsftWYO 07.SeS

b. Degraded'vol go owable Value l ith a ti delay of $/il,3.I'.3 l m (3683' i ~(20] *- ) seconds 4 i

i Dei dad voltage Trip Setpoint i if3746]Vwithatimedelayof

/20) [ -] seconds.

/

\ ,

4

.)

l n org . . . . - _ - .

'3'g*g..... _.

! NoF reyuired.bo be, pe.rformed., br OE I

Nrb'me, d. riven AFuJ pump unbiL 2.4 )

13 hours cJkr SG pressur6 is t 9mpsp, l __......- .-- ------ s-Ye#8, avi:Lio.cp Feebder 54dem is months on o., STYsGERE.D j ESF RE5ADNSE THE For leu of 4LQe.

a.nd DegM Vo L % o n M e # ,/(e k V ESF boseSMMin C'N' l l

h WOG STS 3.3-46 Rev. O, 09/28/92 1

l h0&-1995 12:19 FROM UOGTLE TECH. SUPPORT TO SNC LC Pb l

J CREFS Actuation Instrumentation j 3.3.7 4

i SURVE!LLANCE REQUIREMENTS (continued) i 2

i SURVEILLANCE FREQUENCY

! SR 3.3.7.3 Perfom ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST j

BASIS 1

i j - 5" 3.3.7.0 "^ 1G ".".". Z ""'.* Y 75" .

?. ,!. i..;.. - i g ,y _-.. . .

i yElvf " '"

3 l

i 4

,.2.._

i N/A VE&P

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Y VG *M. En~oYs'nr'W!nYss~riiiT @hFe&l~

- . . - - ~~~ ~ * ' ^~~4 y*18

] SR 3.3.7.f Perfom TAD 0T. A months l

SR 3.3.7. Perfom CHANNEL CALIBRATION. months )

sR 3,3.7,6 VerJ ESF REs2N56 TIME fo r rasbo- l8 mon +bs o nibes uaiWn Uimit,

& Q STAGGERED TEST Basis, i

i i

i a

i

!I 7

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1 l WOC STS 3.3-55 Rev. O, 09/28/92 i

,NOV-06-1995 12:19 FROM UDGTLE TECH. SUPPORT TO SNC ENG/LIC P.04 i*

i CREFS Actuation Instrumentation 3.3.7

]

Telete 3.3.71 (page 1 of 1)

' /

Casrs Actatten 8setrumentation i

l puuCTlas usept h s ausvtILLAmts apenageufs TRIP 857P0157 i 1. IIenust Inittetten goo 4em sa 3.3.7 , un

2. 4" .(2.perumh

._._ 88 3.3.7.3 mA

.Autaastle

.t ti. iAetientian Leels eruf -

1

- . . . . . -;;.:.3

, 3. esueve6-easapeestseeeen-k k at ER

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.2 s (2) et/hr yg m,Q 1,

% Centret seen Air Inte q w..es .ee, Kuzeuum,+);sa 3.3.7.1 i:!:;3 sN i 3

! 4. SafetyInjection Refer to LCD 3.3.2, "E Instrum mtstion. Firstion 1. for ett j intstetten festions irements.

i SR 3.L7.b 7 i

l i

I

! 1 4 1 d

i

, e h

. l I

i i

j a

4 WOG STS 3.3-56 Rev. O, 09/28/92 l

4 The following pages replace and supplement the existing pages behind the Enclosure 4b tab for Chapter 3.3, Volume 3.

3 l

INSERT FOR PAGE B 3.3-58 (RTS)

SR 3.3.1.16 SR 3.3.1.16 is the performance of a COT for the low fluid oil pressure portion of the Turbine Trip Functions as described in SR 3.3.1.7 except that the Frequency is after each entry into MODE 3 for a unit shutdown and prior to exceeding the P-9 interlock trip setpoint. The surveillance is modified by two Notes. Note I states that the surveillance may be satisfied if performed within the previous 31 days. Note 2 states that verification of the setpoint is not required. The Frequency ensures that the turbine trip on low fluid oil pressure channels is OPERABLE after each unit shutdown and prior to entering the Mode of Applicability (above the P-9 power range neutron flux interlock) for this instrument function.

,NOV-06-1995 12:20 FROM UDGTLE TECH. SUPPORT TO SMC ENG/LIC P.07 i ..

'* LOP iMHeav9 Instrumentation l B 3.3.5 i

BASES l SURVEILLANCE SR 3.3.!.# (continued) -

i REQUIREMENTS

verification that the trip occurs within the required time delay, h

! A CHANNEL CALIBRATION is performed every months, or

approximately at every refueling. CHANNEL CALIBRATION is a
complete check of the instrument loop, including the sensor.

i The test verifies that the channel responds to a measured .

{

parameter within t n c ssary range and accuracy.

{ The F quency of months is based on operating i expe ence and consistency with the typical industry i

efu ing cycle and is justified by the assumption of an 1 month calibration interval in the determination of the l magnitude of equipment drift in the setpoint analysis.  ;

~

)

InsEE.7 C R 3.3,T,3) f REFERENCES 1. FSAR, Section .3[ sases euswsmn  :

1 2. FSAR, Chapter 15 .  !

TSC. l l  :. " n rm.;Ta aisf sm

,, i 5ny....;. .ttt;t!:;;; n;;;,. I

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j 3, F5AN, a.ka,p k er Ho -

i i

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b?, /MclW Alh fe $llMedblt YdlWe

>3G83 VWM a has c44 7 m's zo sM
Dg/We/ vo/by 1?y sepuH 4

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1 i WOG STS B 3.3-150 Rev. O, 09/28/92 l

o

- . INSERT SR 3.3.5.3 RESPONSE TIME TEST l BASES DISCUSSION  !

ON PAGE B 3.3-150 OF ESF LOSS OF POWER TS BASES l

! l SR 3.3.5.3 r

This SR ensures the individual channel ESF RESPONSE TIMES with and without offsite l

. power for the AFW System are less than or equal to the maximum values assumed in the accident analysis. Response Time testing acceptance criteria are included in the FSAR,  !

Chapter 16 (Ref.3). Individual component response times are not modeled in the l

~

analyses. The analyses model the overall or total elapsed time, from the point at which the parameter exceeds the Trip Setpoint value at the sensor, to the point at which the  ;

equipment in both trains reaches the required functional state (e.g., pumps at rated discharge pressure, valves in full open or closed position).  ;

For channels that include dynamic transfer functions (e.g., lag, lead / lag, rate / lag, etc.), the response time test may be performed with the transfer functions set to one with the i resulting measured response time compared to the appropriate FSAR response time. l Alternately, the response time test can be performed with the time constants set to their i nominal value provided the required response time is analytically calculated assuming the time constants are set at their nominal values. The response time may be measured by a j

. series of overlapping tests such that the entire response time is measured.

ESF RESPONSE TIME tests are conducted on an 18 month STAGGERED TEST BASIS. Testing of the final actuation devices, which make up the bulk of the response time, is included in the testing of each channel. The final actuation device in one train is tested with each channel. Therefore, staggered testing results in response time  ;

verification of these devices every 18 months. The 18 month Frequency is consistent with the typical refueling cycle and is based on unit operating experience, which shows that random failures ofinstrumentation components causing serious response time  !

degradation, but not channel failure, are infrequent occurrences.

This SR is modified by a Note that clarifies that the turbine driven AFW pump is tested within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after reaching 900 psig in the SGs.

i k

1

,NOV-06-1995 12:21 FROM UOGTLE TECH. SUPPORT TO SNC Er& LIC P.09 CREFS Actuation Instrumentation B 3.3.7 BASES S

4 SURVEILLANCE SR 3.3.7./

REQUIREMENTS (continued) A CHANNEL CALIBRATION is performed every 1 months, or

approximately at every refueling. CHANNEL CALIBRATION is a 4

complete check of the instrument loop, including the sensor.

The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.

l The Frequency is based on operating experience and is consistent with the typical industry refueling cycle.

?

REFERENCES 1. ' Cr ;;;7: a a, E ;n---. ,

o., , ., . . . , m o ,,

uJoCr-26-0 Q 4:o SCS Letle,- seGP-(.v-cotsj da} Z3, I988. TmM/tdWAof PMTc s,

l / FSAR.ci I

2. VEGP gatcutATen & KloCNA.09.O/, Obo!

l Qty > f/lfK*Tdr>idyiAca:h'oi7S, 2.1 odh, l l

' /988,

3. FS A R, Ghc.pYe.r 16 _j l

TN6ELT $R 3 3 7.6 Bo.zattdastusion d

WOG STS B 3.3-168 Rev. O, 09/28/92 1

l ,

e INSERT SR 3.3.7.6 RESPONSE TIME TEST '

BASES DISCUSSION ON PAGE B 3.3-168 OF CREFS ACTUATION INSTRUMENTATION TS BASES SR 3.3.7.6 This SR ensures the individual channel ESF RESPONSE TIME for the CREFS radiogas monitor actuation instrumentation is less than or equal to the maximum values assumed in the accident analysis. Response Time testing acceptance criteria are included in the FSAR, Chapter 16 (Ref. 3). Individual component response times are not modeled in the analyses. The analyses model the overall or total elapsed time, from the point at which the parameter exceeds the Trip Setpoint value at the sensor, to the point at which the '

equipment in both trains reaches the required functional state (e.g., pumps at rated discharge pressure, valves in full open or closed position).

For channels that include dynamic transfer functions (e.g., lag, lead / lag, rate / lag, etc.), the response time test may be performed with the transfer functions set to one with the resulting measured response time compared to the appropriate FSAR response time.

Alternately, the response time test can be performed with the time constants set to their nominal value provided the required response time is analytically calculated assuming the time constants are set at their nominal values. The response time may be measured by a series of overlapping tests such that the entire response time is measured.

ESF RESPONSE TIME tests are conducted on an 18 month STAGGERED TEST BASIS. Testing of the final actuation devices, which make up the bulk of the response time, is included in the testing of each channel. The final actuation device in one train is tested with each channel. Therefore, staggered testing results in response time verification of these devices every 18 months. The 18 month Frequency is consistent with the typical refueling cycle and is based on unit operating experience, which shows that random failures ofinstrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences.

i l

e.

The following pages replace and supplement the existing pages behind the Enclosure 5 tab for Chapter 3.3, Volume 3.

i i

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

o

e ,

VEGP ITS Conversion -

Enclosure 5 -Justifications for  ;

Differences from NUREG-1431 Chapter 3.3 -Instrumentation LCO 3.3.2 ESFAS ClIANGE (

NUMBER JUSTIFICATION 26 The format of the Note modifying Conditions C, D, E, G, H, I, and K was corrected to show that it modifies all the Required Actions. i 27 The frequency of SR 3.3.2.9 is revised to 18 months from once per reactor trip breaker cycle consistent with current licensing basis.  !

28 A Note is added to the Mode of Applicability for Function 7a " Semi- l Automatic Switchover to Containment Sump, Automatic Actuation Logic .

and Actuation Relays". The new Note (h) requires only one train of actuation logic and relays to be operable in Mode 4. This change is consistent with the requirement in LCO 3.5.3 for only one train of RHR to be operable in this Mode. This change provides consistency between the - .

instrument and system LCOs.

29 The NUREG-1431 requirement for a Channel Check of the Pressurizer Pressure P-11 ESFAS function on Table 3.3.2-1 is deleted. This Channel

Check is not required by the current VEGP TS for the ESFAS P-11 l function. The actual P-11 interlock function is verified operable by the

~

performance of a 92-day COT and an 18-month Channel Calibration. The operation of the pressurizer pressure channels associated with the P-11 interlock are also confirmed operable by the Pressurizer Pressure reactor trip and SI function Channel Checks required by the RTS and ESFAS TS  !

for the same channels. Therefore, the Channel Check of the interlock status lights required by NUREG-1431 has no impact on the reliability or operability of the P-11 interlock at VEGP.

i Chapter 3.3 E5-20 November 6,1995 e  !

-i

e.

t g; '

VEGP ITS Conversion ,

Enclosure 5 - Justifications for i

Differences from NUREG-1431 Chapter 3.3 -Instrumentation .

2 LCO 3.3.5  ;

LOSS OF POWER (LOP) DIESEL GENERATOR (DG) START INSTRUMENTATION CilANGE.

i NUMBER JUSTIFICATION VEGP specific Trip Setpoint and Allowable Value. The revised surveillance is consistent with the current VEGP TS requirements.

I1 Due to the complexity of the setpoints and allowable values for loss of and degraded voltage, this information will be moved to the Bases for SR i 3.3.5.3.

12 The Note modifying Required Action A.1 would be revised to allow either the inoperable channel or the channel to be tested to be bypassed for surveillance testing of the remaining operable channels. The net elTect is the same. If the inoperable channel is bypassed, the operable channel must be tested in trip. If the operable channel is tested while it is bypassed, the  ;

inoperable channel must remain in trip. Either way, one channel will be bypassed and one channel will be in trip. The existing VEGP TS currently provide for this. Therefore, the proposed change is consistent with current licensing basis.

13 At VEGP the Loss of Power instrumentation actuates the Auxiliary Feedwater pumps as well as the Diesel Generator. The Loss of Voltage ,

and Degraded Voltage AFW Functions were moved from the ESFAS TS into the proposed ESF Bus Loss of Power TS to consolidate the functions performed by this instrumentation. Generic change NRC-022-Cl deleted the response time testing requirement (NUREG-1431 SR 3.3.5.3) for the Emergency Diesel Generator on loss of voltage and degraded voltage signals. liowever, the VEGP safety analyses include assumptions for the AFW system response to automatic start signals with and without offsite  !

power available. The VEGP FSAR (Table 16.3-2) contains an explicit line item for the AFW system response to both loss of voltage and degraded voltage on the ESF buses. In addition, the current ESFAS TS contains an SR for response time testing this instrument function. l Therefore, a VEGP specific SR 3.3.5.3 to verify the AFW system response time to loss of voltage and degraded voltage on the 4.16 kV ESF buses is Chapter 3.3 ES-28 November 6,1995

- m- g

, 1

.?

VEGP ITS Conversion Enclosure 5 - Justifications for ,

Differences from NUREG-1431 Chapter 3.3 -Instrumentation LCO 3.3.5 4

LOSS OF POWER (LOP) DIESEL GENERATOR (DG) START INSTRUMENTATION i

CIIANGE l NUMBER JUSTlFICATION l

- added to the ESF Bus Loss of Power TS. The proposed SR is the equivalent of the Current TS ESFAS response time test requirement l- (4.3.2.2) that applies to the current AFW Loss of Voltage and Degraded Voltage Functions in the ESFAS TS. The proposed SR also includes a i Note that allows a delay in testing the turbine-driven AFW pump until steam generator pressure reaches an appropriate value for operating the pump. The Note in proposed SR 3.3.5.3 is consistent with the Note in the NUREG-1431 ESFAS TS for other AFW response time testing.

1 P

' Chapter 3.3 E5-28a November 6,1995

VEGP ITS Conversion Enclosure 5 - Justifications for i Differences from NUREG-1431  !

Chapter 3.3 - Instrumentation  !

i LCO 3.3.7 CONTROL ROOM EMERGENCY FILTRATION SYSTEM (CREFS)

CIIANGE ,

NUMBER JUSTIFICATION  !

i

-7 A VEGP specific SR for response time testing the radiogas monitor  !

actuation instrumentation has been added to the Improved CREFS TS.

The radiogas monitors are required to actuate CREFS for a fuel handling r accident in the fuel handling building. The analysis associated with this l

postulated event assumes a response time which includes the radiogas ,

monitor actuation. The CREFS radiogas monitors are specified in the i current VEGP ESFAS TS which has a surveillance requirement for  ;

response time testing. The addition of this SR to the Improved CREFS TS  ;

is consistent with the surveillance requirement (4.3.2.2) in the current ]

VEGP ESFAS TS.

l L

i r

e

J

+

l

+  ;

s .

l Chapter 3.3 , E5-30a November 6,1995 I

' l

1 0

w s.

O The following page replaces the corresponding page behind the Enclosure 4b tab for Chapter 3.7, Volume 6.

l

,NOV-06-1995 12:24 FR0ri UOGTLE TECH. SUPPORT TO SNC ENG/LIC P.17

, AFW System

! 8 3.7.5

! BASES (continued)

' y6 RVEILLANCE SR 3.7.5.1 ,

REQUIREMENTS g Verifying the correct ali neent for manual, power operated, i

The correckpoSNioD and automatic valves in t e AFW System water and steam 4 is We posihan 4 I supply flow paths provides assurance that the proper flow

gum paths will exist for AFV ooeration.g This SR does not apply

'g8 g to valves that are locked, sea'et, or otherwise secured in

, O* g position, since they are verified to be in the correct position prior to locking, sealing, or securing. This SR S T +htpWU i

also does not apply to valves that cannot be inadvertently i

Oak time,j iM d,pri misaligned, such as check valves. This Surveillance does I lowpowe,r- not require any testing or valve manipulation; rather, it

{ op on a _ involves verification that those valves capable of being i

,g g Q 'mispositioned are in the correct position.

i P~M M Th. 31 day rr.quency is bas.d on en,ine. ring judgment, is res,oire.fne45 8 N8' - consistent with the procedural controls governing valve

! 7ednn's.) Sper' MAYA,on operation, and ensures correct valve positions. '

i c.r4y515 MR.-

Crew. ) E _3_.7.5.2 _

1 Nge,-/3-C I-Al is SR verifies that the AFW pumps develop sufficient i d a pressure to deliver the required flow at t 1

! open pr of the MSSVs. Because it is unde e to

IN5fA.T--+ introduce co into the steam generato ile they are i operating, this to is performed ecirculation flow.

Periodically comparing refe differential pressure developed at this reduced etects trends that might be j indicative of incipie ilure. formance of inservice

testing discuss the ASME Code, Se n XI (Ref. 2)

(only requir t 3 month intervals satis this j

requir . The (31] day Frequency) on a STAGG TEST results in testing each pump once every 3 mont ,

equired by Reference 2.

This SR is modified by a Note indicating that the SR should i

' j be deferred until suitable test conditions are established.

This deferral is required because there is insufficient steam pressure to perform the test.

I SR 3.7.5.3 3

'This SR verifies that AFW can be delivered to the appropriate steam generator in the event of any accident.or j (continued)

WOG STS 8 3.7-29 Rev. O, 09/28/92 1

1 TOTAL P.17

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