Text

Proposed Tech Specs,Changing Functions of Reactor Protection Sys & ESFAS Instrumentation.Description & Justification for Changes & NSHC Determination Encl
	ML20214M882
Person / Time
Site:	Sequoyah
Issue date:	05/22/1987
From:	; TENNESSEE VALLEY AUTHORITY
To:	;
Shared Package
ML20214M874	List: ML20214M873; ML20214M882;
References
	TAC-R00128, TAC-R00129, TAC-R128, TAC-R129, NUDOCS 8706010458
	Download: ML20214M882 (33)
	v • d • e

.

ENCLOSURE 1 PROPOSED TECHNICAL SPECIFICATION CHANGES SEQUOYAH NUCLEAR PLANT UNITS 1 AND 2 DOCKET NOS. 50-327 AND 50-328 (TVA-SQN-TS-87-20)

PROPOSED AMENDMENT TO REACTOR PROTECTION SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION List of Affected Patos Unit 1 3/4 3-12 3/4 3-16 3/4 3-17 3/4 3-19 3/4 3-21a 3/4 3 3/4 3-23 3/4 3-26 3/4 3-28 3/4 3-31 3/4 3-36 3/4 3-37a Unit 2 3/4 3-12 3/4 3-17

.. 3/4 3-19 3/4 3-21a 3/4 3-22 3/4 3-23 3/4 3-26 3/4 3-28 3/4 3-31 3/4 3-36 3/4 3-37a 3/4 3-38 0706010450 070522 PDR ADOCK 05000327 P PDR

e 4'

" TABLE 4.3-1 (Continued)

E

REACTOR TRIP SYSTEN INSTRUNENTATION SURVEILLANCE REQUIRE E NTS

_k

-E CHANNEL N00ES IN WHICH CHAletEL FUNCTIONAL SURVEILLANCE CHANNEL E "

CHECK CALIBRATION TEST REQUIRE 0 Q FUNCTIONAL UNIT .

R Q 1, 2 Main Steam Generator Water S 14.

Level--Low-Low "31 R Q 1, 2 Steam /Feedwater Flow Mismatch and S 15.

Low Steam Generator Water Level '

N.A. R - N 1

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

17. Underfrequency - Reactor Coolant Pumps

~

i

18. Turbine Trip -

Low Fluid Oil Pressure N.A. N.A. S/U(1) 1 w A. S/U(1) I Turbine Stop Valve Closure N.A. N.A. .

2 B. -

M.A. N(4) 1, 2 w 19. Safety Injection Input from ESF M.A.

M.A. N.A. N(5) and S/U(1) 1, 2, and

U 20. Reactor Trip Breaker ,

N.A. M.A. N(5) 1, 2, and *

21. Automatic Trip L'ogic

22. Reactor Trip System Interlocks 2, and

Intermediate Range N.A. R S/U(8)

A.

Neutron Flux, P-6 Power Range Neutron M.A. R S/U(8) 1 8.

. Flux, P-7 Power Range Neutron N.A. R S/U(8) 1 C.

f Flux, P-8 Ui j ;; ! D. Power Range Neutron M.A. R S/U(8) 1, 2 Flux, P-10

! F: P Turbine Impulse Chamber M.A. R S/U(8) 1 j ;;; E. -

- - Pressure, P-13 Power Range Neutron M.A. R S/U(8) 1 jf: ; F.

Flux, P-9 S/U(8) 1, 2, and *

!$ ll G. Reactor Trip, P-4 M.A. )t"M.A.

t, ,

)

1 i ..

' 2 N TABLE 3.3-3 (Continued) o ,

8 ENGINEERED SAFETY TEATURE ACTUATION SYSTEM INSTRUMENTATION x

s '

MINIMUM

-E TOTAL NO. CHANNELS TUNCTIONAL UNIT CHANNELS O OF CilANtiELS TO TRIP APPLICABLE OPERABLE MODES ACTION COINCIDENT WITH EITilER T,,g--Low-Low ##

1, 2, 3 four Loops 1T / loop Operating '9 2I any 1T any

"'9 - **9 16*

loops 3 loops OR, COItJCIDENT WIIII Steam Line Pressure-Low -

R45 1, 2, 3 m Tour toeps 1 pressure /

h Operating 2 pressures I pressure loop any loops 16*

s.,

any 3 loops

, 2. CONIAIF#!ENT SPRAY .

e E4h

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

b. 20 Automatic Actuation 2 Logic 1 2 1,2,3,4 15

c. Containment Pressure-- 4 2 Itigh-liigh 3 1,2,3 18

3. CONIAlf#1ENT ISOLATION

.< , a. Phase "A" Isolation

1) Manual 2 E;! I 1 2 j i 1,2,3,4 20

2) From Safety Injection 2 i', [ 1 2 1,2,3,4 Automatic Actuation 15

n Lo9i c j i.

9 , y ; w ws ast k V M 'I Y.

O *

' 5 TABLE 3.3-3 (Continued)

, =

E ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION -

8 E .

MINIMUM TOTAL No. CilArtilELS CilANNELS APPLICA8tE E FUtiCTI0t1AL Utill 0F CitAfirJELS TO IRIP OPERABLE HOOES ACTION O

r b. Phase "B" Isolation

1) Manual 2 1# 2 1,2,3,4 20

2) Automatic 2 1 2 1, 2, 3, 4 15 Actuation Logic

3) Containment 4 2 3 1, 2, 3 18 Pressure-liigh-liigh r c. . Containc:ent Ventilation -

t' Isolation

c.

l

';' 1) Itanual 2 1 2 1, 2, 3, 4 19

! ?~,

2) Automatic Isolation 2 ,1 2 1, 2, 3, 4 15 Logic

3) Containment Gas 2 1 1 1, 2, 3, 4 19 f toni tor. Radioact iw Ity-liigh *

4) Containment Purge 2 1 1 1, 2, 3, 4 19 Air Exhaust Monitor Radioactivity-Iligh

5) Containment Particu- 2 1 1, 2, 3, 4 19 J [j ?

late Activity sligh RU

. l: L j y .

e h, N x % sw;i Aes auf La openM ne%~**.dy tw aelu lias.

- c; ..

I

l-i

= , -

.n

(-i

~

O)

(

. s

~

m TABLE 3.3-3 (Continued)

E :,

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRt9ENTATION 8

-< l N

e MININIM TOTAL NO. CHA800ELS CHANNELS APPLICA8tE E FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERA 8tE a M00ES ACTION

5. TURBINE TRIP &

FEEDWATER ISOLATION

a. Steam Generator 3/ loop 2/ loop in 2/ loop in 1, 2, 3 16*

Water Level-- any oper- each oper-High-High ating loop ating loop

b. L'- _ =;e Meeu. LQ g

6. AUhILIARY FEEDWATER I J l13 s 3 23

a. Manual Initiation 2 1 2 1,2,3 24 Y*

b. Automatic Actuation 2 1 2 1,2,3 23 Y Logic 5

c. Main Sta. Gen. Water .

Level-Low-Low

1. Start Motor Driven Pumps 3/sta. gen. 2/sta. gen. 2/sta. gen. 1, 2, 3 16*

any sta gen.

11. Start Turbine-Driven Pump 3/sta. gen. 2/sta. gen. 2/sta. gen 1, 7, 3 16*

any 2 sto. gen.

[' = d. S.I.

- ; Start Motor-Driven I

t ; Pug s and Turbine

, ,r -

, i, Driven Pump See 1 above (all S.I. Initiating functions and requirements)

~

2 r u, .

TABLE 3.3-3 (Continued)

[

! = _ ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION I. N I

- c HINIMUM

] = TOTAL NO. CHANNELS FUNCTIONAL UNIT CilANNELS

-< OF CilANNELS TO TRIP APPLICABLE OPERABLE H0 DES w 8. ACTION EfXIINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS

a. Pressurizer Pressure - 3 2 Hot P-11 2 1,2,3 22a

b. T ,g - P-12 4 2 3 1, 2, 3

c. 22b Steam Generator 3/ loop

-Level P-14 2/ loop 3/ loop

.s 1, 2 22c u any loop '

D 9. . - -

AUTOMATIC SWITCI10VER TO

<;> CONT 4ITE!ENT SIRIP ~

=

M RWST Level - Low 4 2 R33 COINCIDENT WITil 3 1,2,3,4 18 Containment Simp Level - liigh 4 2 AND . 3 1,2,3,4 18 Safety Injection (See 1 above for Safety Injection Requirements)

h. A lenRe. AeL.rVay lest Z l 2 05I2s E '5 NY

? *

"! t

!d "l F l$

h

INSTRUMENTATION I

TABLE 3.3-3 (continued)

TABLE NOTATION

Trip function may be bypassed in this MODE below P-11 (Pressurizer Pressure g,81ock of Safety Injection) setpoint.

FP Trip function may be bypassed in this MODE below P-12 (T avg Block of Safety Injection) setpoint, The channel (s) associated with the protective functions derived from the out of service Reactor Coolant Loop shall be placed in the tripped mode.

The provisions of Specification 3.0.4 are not applicable.

ACTION STATEMENTS ACTION 15 - With the number of OPERABLE Channels one less than the Total Number of Channels, be in at least HOT STAN00Y within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUT 00WN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to hours for surveillance yP testing *per Specification 4.3.2.1.1 p ovided the other channel is OPERABLE. 2 ACTION 16 - With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed until performance of S' ACTION 17 -

the next required CHANNEL FUNCTIONAL TEST, provided the inoperable channel is placed in the tripped condition within I hour.

With a channel ssociated with an operating loop inoperable, restore the inoperable channel to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in at least HOT SHUTOOWN within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; however, one channel associated with an operating loop 7p may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1.

ACTION IB - With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is demonstrated within I hour; one additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1.

ACTION 19 - With less than the Minimum Channels OPERABLE, operation may continue provided the containment ventilation isolation valves are maintained closed.

ACTION 20 - With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE

. . . status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT. STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUT 00WN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

( -

j SEQUOYAH , UNIT 1 3/4 3-22 m .- mnn w ., .m e

I' O

Q ,)

INSTRUMENTATION TABLE 3.3-3 (Continued)

ACTION 21 - With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within I hour,

b. The Minimum Channels OPERABLE requirements is met; however, one additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1.

ACTION 22 - With less than the Minimum Number of Channels OPER\8LE, declare the interlock inoperable and verify that all affec'.ed channels of lit the functions listed below are OPERABLE or apply tie appropriate ACTION statement (s) for those functions. Functions to be evaluated,are:

a. Safety Injection Pressurizer Pressure

b. Safety injection D- High Steam Line Flow

(, Steam Line Isolation High SteamiLine Flow Steam Dump

c. Turbine Trip Steam Generator Level High-High -

Feedwater Isolation Steam Generator Level High-High ACTION 23 - With the number of OPERA 0LE channels one less than the Total Number of Channels, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up t houra

, for surveillance testing per Specification 4. .1.

ACTION 24 - With the number of OPERABLE channels one less than the Total Nut er of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUT 00WN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 25 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERA 0LE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated v.tive inoperable kle and take the ACfl0N required by Spectfication 3,7.1.S.

o m,n-

.m o i og16

^

SEQUOYAH - UNIT 1 3/4 3-23 ~ .. ,.1' u___

l TA8LE 3.3-4 (Continued) .

h ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPolNTS 5

5 FUNCTIONAL UNIT TRIP SETPOINT f ALLOWA8tE VALUES .

E 3. Containment Gas Monitor < 8.5 x 10'3 pCl/cc 1 8.5 x 10'3 pCi/cc Radioactivity-High

4. Containment Purge Air Exhaust < 8.5 x 10'3 pCi/cc 1 8.5 x 10'3 pCi/cc Monitor Radioactivity-High

5. Containment Particulate -5 pCi/cc -5 h Activity-High i 1.5 x 10 1 1.5 x 10 Ci/cc

4. STEAM LINE ISCLATION

a. Manual Not Applicable Not Applicable "

b. Automatic Actuation Logic Not Applicable Not Applicable w .

1 c. Containment Pressure--High-High 5 2.81 psig i 2.97 psig y d. Steam Flow in Two Steam lines-- < A function defined as < A function defined as y High Coincident with T --Low-Low follows: A ap correspond- follows: A ap corresponding Or Steae Line PressureUEow ing to 40E of full steam to 44% of full steam flow flow between OE and 20E between OE and 20% load load and then a op and then a Ap increasing increasing linearly to a linearly to a op correspond-op corresponding to ing to 111.5% of full steam 110% of full steam flow flow at full load at full load. .

T ,9 1 540*F 7,,,3 538*F 3 600 psig steam 3 580 psig steam line pressure line pressure

5. TU481NE IRIP AND FEEDWATER ISOLATION

a. Steam Generator Water. level-- < 75% of narrow range < 76% of narrow range Iligh-High Instrument span each steam Instrument span each steam generator generator .

k M & K Nse L*3't g, j, ~

w s s, ..-

TABLE 3.3-4 (Continued)

~ ~

E .

j ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPO ^

5 1

Att0VABLE VALUES TRIP SETPOINT e FUNCTIONAL UNIT C

5 8. ENGINEERED SAFETY FEATURE ACTUATION .

".- SYSTEM INTERLOCKS (Continued) e . .

b. T avg Prevents Manual Block of Safety '

Injection P-12 5 540*F ,

1 542'F

c. T,,g e

Manual Block of Safety Injection.

Steam Line Isolation, Block Steas .

> 538'F Dupp > 540'F u -

1 d. Steam Generator Level w Turbine Trip, Feed <ater Isolation 4 P-14 (See 5. above) em gig

9. AUTCMATIC SWITCHOVER 10 CONTAIPMENT 512:P

. 130" from tank base 130" 1 4' from tank base

a. EVST tevel - Low COINCIDENT WITH Contairsent Susp Level - High 30" above elev. 680' 30" i 2.5" above elev. 680' AX3 Safety Injection (See 1 above for all Safety Injection Setpoints/ Allowable Vab

)[j,I pl.A

h. h h u M .

EI m L o s c.- g j, b i m.

-1 witchover of R10t pts:p suction from the RWST to containment str

{l1e

~ ~

be esploye un o.. .

' - r- ,

R18 ,

- uring l 5 Autoaatic switchover i ..

. . .. ect for a period not to exceed 30 days (July 18,1982).

bolske,.

~

i

~.',

TABLE 3.3-5 (Continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES IN!T!ATING $!GNAL AND FUNCTION . RESPONSE TIME IN SECONOS

6. Steam Flow in Two Steam Lines-High -

Coincident with 5 team Line Pressure-Low

a. Safety Injection (ECCS) i 13.0C7)/23.0(1)

b. Reactor Trip (from SI) 1 3.0 '

c. Feedwater Isolation < 8.0(2)

d. Containment Isolation-Phase "A"(3) i 18.0(8)/28.0(8)

e. Containment Ventilation Isolation Not Applicable

f. Aux 111ary Feedwater Pumps 1 60

g. Essential Raw Cooling Water System 1 65.0(8)/75.0(I)

h. Steam Line Isolation < 8.0

1. Emergency Gas Treatment System h38.0(8)

) 7. Containment Pressure--Hich Hich

) a. Containment Spray

$ 58.00(8)

b. Containment Isolation-Phase "B" 1 65(8)j73(9)

c. Steam Line Isolation i 7.0

d. Containment Air Return Fan R16

> 540.0 and 1 660 i 8. Steam Generator Water Level--Hich-High

a. Turbine Trip ".. G;.c h 4 1 2.5 ,

b. Feedwater Isolation i 11.0(2)

9. Main Steam Generator Water Level -

Low-Low

a. Motor-driven Auxiliary 1 60.0 Feedwater Pumps (4)

b. Turbine-driven Auxiliary < 60.0

~

Feedwater Pumps (5)

Il j

] uinn.-w IYl N 4 ) (,a V 4 w

b

$EQUOYAH - UNIT 1 3/4 3-31 f. ;ie-oi. 6. U-

a f -

E TABLE 4.3-2 (Continued) -

i k ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION N 5bsVEILLANCE REQUIREMENT 5 C

3, -

CHANNEL

- CHANNEL CHAlesEL M00ES IN idHICH

_ FUNCTIONAL UNIT FUNCTIONAL

" _ CHECK SURVEILLANCE CALIBRATION TEST

4) Containment Purge Air REQUIRED S R Exhaust Monitor Radio- M 1,2,3,4 activity-High

5) Containment Particulate 5 R Activity-High .

M 1,2,3,4

4. STEAM LINE ISOLATION g a. Manual i M.A. N.A.

t

~R 1, 2, 3 y b. Automatic Actuation Logic N.A. N.A. ,' R51 -

M(1) 1, 2, 3

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

d. Steam Flow in Two Steam S R Lines-High Coincident with Q 1, 2, 3 T,,g--Low-Low or Steam Line Pressure--Low

5. TURBINE TRIP AND FEEDWATER

ISOLATION i I? a. Steam Generator Water

! ;M S R I, ; Level--High-High Q 1, 2, 3

! ;l,I 6.

13. A M ara d.- A p

< - AUXILIARY FEEDWATER 84 W A- Ml8) i f} a. Manual N.A.

M.A. R -

t, is 3 1,2,3 h ~

b. Automatic Actuation Logic R51 l : -

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

[1 ,

.- ~ .

i s

M _ TABLE 4.3-2 (Continued) -

e ' ,"

3 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION

, E 50RVEItLANCINEQUIREHENTS

" CHANNEL CHANNEL MODES IN WHICH FUNCTIONAL UNIT CHANNEL FUNCTIONAL w _ CHECK SURVEILLANCE CALIBRATION TEST REQUIRED

8. ENGINEERED SAFETY FEATURE .

ACTUATION SYSTEM INTERLOCKS -

. a. Pressurizer Pressure, '

! N.A. R(2) N.A.

P-11 ' 1,2,3 i

) b. T"V9, P-12 N.A. R(2) N.A. 1, 2, 3 R51 i c. Steam Generator .

N.A. .

l' 3 Level, P-14 i R(2) ~ ~ . . N.A.

1, 2 .

Y 9. AUTCHATIC SWITCHOVER To

-[ -

CONTAINMENT SUMP ' d~

a. RSWT Level - Low

! S R COINCIDENT WITH M 1,2,3,4

Containment Sump Level - High 5 R j

AND M 1, 2, 3, 4 Safety Injection (See 1 above for all Safety Infection Surveillance Requirements) l 'L. A. L AJ 1:n i+ x.n. pg, mza

l. ,, 2., s, y 3

n' t,

1;

)\

s

$'j

'.J ;; :-

' .3 t . -,- o ,.. ;

i *l.

) .

23 {f o

~- i. x.. l f

[

'. [ '

~

TABLE 4.3-1 (Continued) '

m" -

x

.k REACTOR TRIP SYSTEM INSTRtBENTATION SURVEILLANCE REQUIREMENTS E CHPMMEL MDOES FOR WNICN CHANNEL FUNCTIONAL SURVEILLANCE 15 CHANNEL' e TEST REQUIRED

~

CHECK CALIBRATION g FUNCTIONAL UNIT 1, 2

- R16 S R q

" 15. Steam / Fee & ster Flow Mismatch and Low. Steam Generator Water Level A M 1

16. Undervoltage - Reactor Coolant N.A. ,

Pumps M 1

17. Underfrequency - Reactor Coolant N.A. R Pumps i

18. Turbine Trip .

N.A. S/U(1) - 1

-N.A.

$ A. Low Fluid Oil Pressure N.A. S/U(1) 1

- 8. Turbine Stop Valve Closure N.A.

U N.A. M.A M(4) 1, 2

19. Safety Injection Input from ESF -

N.A. M(5) and S/U(1) 1, 2, and

Reactor Trip Breaker N.A.

20.

M.A. M(5) 1,.2, and *

21. Automatic Trip Logic N.A. ,

22. Reactor Trip System Interlocks S/U (8) 2, and

N.A.

Intermediate Range R i ii A.

Neutron Flux, P-6 l l4 S/U (8) 1

8. Power Range Neutron N.A. R

! t; .

t ;'o Flux, P-7 S/U (8) 1 3 " C. Power Range Neutron N.A. R Flux, P-8 iFy s e D. Power Range Neutron N.A. A S/U (8) 1, 2 y Flux, P-10 S/U (8) 1 E. Turbine Impulse Chamber N.A. R Pressure, P-13 F. Power Range Neutron ,

S/U (8) 1 .

Flux, P-9 N.A. R. 1, 2, and

G. Reactor Trip, P-4 N.A. ,

Eff.A. S/U (8) .

Q

'd, e*%

. ~

- /.

] .

1ABlE 3.3-3 (Continued) '

"j .

8 ENGINfiHED SAfLIV iiAIURE ACIUATION SYSilH IN51RilHENTAT10N s

x HINIH0H 10TAL NO. CilAtlNELS CllAt4NEI S g fullCll0NAL llHil APPLICABLE Of CilAi!NLIS 10 l RIP Ol'[RAul E m HOOLS ACil0N y 2. CONIAINHitti SPHAY

a. Manual 2 1A 2 1, 2, 3, 4 20 l>. Automat it. Actuation '

2 1 2

, l ogic 1, 2, 3, 4 15

c. Containment Pressure-- 4 2 3 1, 2, 3 liigfriligh 18

$ 3. Colil Altilll HT ISol ATION e.,

', a. Phase "A" Isolation

'8 I) Hanual 2 I 2 1, 2, 3, 4 2 11

7) I s um Saf ety in.js r:l ion 2 1 2 1,2,3,4 Antomatic Acluation 15 liigic

, 1: .

Phase "in" Isolation

1) Hanual 2 Ik

2) Automatic 2 1 2 1, 2, 3, 4 20 Actuation logic 2 1, 2, 3, 4 .15 i ,

3) Containment 4

, 2 3 Pressure-liigh-liigh 1, 2, 3 3g

-Y fwo sa M es md be ot*(ggj $;pdkneedy ' for C*S* W '

i

'\ ,

,- 9 -

TABLE 3.3-3 (Continued) -

r y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION -

. 8

'3

, y MINIMUM

, TOTAL NO. CHANNELS CHANNELS APPLICABLE c FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION i U COINCIDENT WITH EITHER N T --Low-Low 1, 2, 3

"'8 Four Loops 1 T8/ loop 2 T '8 any 1T 16*

1 Operating 100$ 310$ $ any OR, COINCIDENT WITH #

Steam Line Pressure- 1,2,3 Low i

! Four Loops R 1 pressure / 2 pressures 1 pressure 16*

Operating loop any loops any 3 loops ,

"e

-4 ;

4 t 5. TURBINE TRIP &

FEEDWATER ISOLATION .

a. Steam Generator 3/ loop 2/ loop in 2/ loop in 1, 2, 3 16*

Water Level-- any oper- each oper-High-High ating loop ating loop i fi,- ' '

i l -l l

\o . Al.mik Aclanlien in:<. .

L i t< r i 2 X3 i

t

- g1 ,.- )y>3 \

a< e i l fi .

I i s l $ !

i l

1 1

TABLE 3.3-3 (Continued) .

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM c TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION N 8. ENGINEERED SAFETY FEATURE

ACTUATION SYSTEM INTERLOCKS

a. Pressurizer Pressure - 3 2 2 -

1, 2, 3 22a

, Not P-11 R18

b. T,yg - P-12 4 2 3 1,2,3 22b

' c. Steam Generator 3/ loop 2/ loop 3/ loop 1, 2 22c ~

Level P-14 any loop

9. AUTOMATIC SWITCHOVER TO w CONTAINHENT SUMP m .

U E.a. RWST Level - Low 4 2 3 1, 2, 3, 4 18 COINCIDENT WITH Containment Sump Level - High 4 2 3 1,2,3,4 18 AND Safety Injection (See 1 above for Safety Injection Requirements)

b. 2 2 gg Omk&se- Achalise L9:s , g, 2, 3, y it if I22 ll (n !

3 f

I TABLE 3.3-3 (Continued)

TABLE NOTATION o -, Trip function may be bypassed in this MODE below P-11 (Pressurizer Pressure gBlock of Safety Injection) setpoint.

Trip function may be bypassed in this MODE below P-12 (T Injection)setpoint. avg Block of Safety g ,The channel (s) associated with the protective functions derived from the

,out of service Reactor Coolant Loop shall be placed in the tripped mode.

The provisions of Specification 3.0.4 are not applicable.

ACTION STATEMENTS ACTION 15 -

l With the number of OPERABLE Channels one less than the Total i

Humber of Channels, be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up toghoursfor surveillance testing per Specification 4.3.2.1.11provided the other channel R2 is OPERABLE.

\g ACTION 16 -

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed until performance of the next required CHANNEL FUNCTIONAL TEST, provided the inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

h ACTION 17 -

With a channel associated with an operating loop inoperable, restore the inoperable channel to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 1

l or be in at least HOT SHUTOOWN within the following 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; l

however, one channel associated with an operating loop may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per R2 Specification 4.3.2.1.1.

ACTION 18 -

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is demonstrated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; one additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1. R2 ACTION 19 -

With less than the Minimum Channels OPERABLE, operation may continue provided the containment ventilation isolation valves are maintained closed.

ACTION 20 -

With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

\.

{d SEQUOYAH - UNIT 2 3/4 3-22 N

e

, TABLE 3.3-3 (Continued)

ACTION 21 - With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ,

b. The Minimum Channels OPERABLE requirements is met; however, one additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1. R2 ACTION 22 - With less than the Minimum Number of Channels OPERABLE, declare the interlock inoperable and verify that all affected channels of the functions listed below are OPERABLE or apply the appropriate ACTION statement (s) for those functions. Functions to be evaluated are:

a. Safety Injection Pressurizer Pressure

b. Safety ~ Injection High Steam Line Flow .

Steam Line Isolation High Steam Line Flow Steam Dump

. ,rm.

(,1< c. Turbine Trip .

Steam Generator Level High-High Feedwater Isolation Staam Generator Level High-High ACTION 23 - With the number of OPERABLE channels one less than the Total Number of Channels, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTOOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to Zhour.s for R2 surveillance testing per Specificatio'; 4.3.2.1.1 ACTION 24 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 25 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable. channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

l Q,d M SEQUOYAH - UNIT 2 3/4 3-23

e TABLE 3.3-4 (Continued) .

$ ENGINEERED SAIETY FEAIURE AC10A110N SYSTEM INSTRUMENTATION 1 RIP SEIPOINIS O

1 RIP SETPOINT ALLOWA8LE VALUES hFUNCil0NALUNil

-3 $ 8.5 x 10'3 pCi/cc

3. Containment Gas Monitor 5 8.5 x 10 pCi/cc

[ Radioactivity-liigh

~3

< 8.5 x 10 -3 pCi/cc

~

N 4. Containment Purge Air Exhaust. Ci/cc $ 8.5 x 10 Monitor Radioactivity-liigh

-5 -5 Ci/cc

5. Contalement Particulate 5 1.5 x 10 Ci/cc 5 1.5 x 10

. Ac tivity-liigh .

4. STEAM LINE l'.0LATION '

a. Manual Not Applicable Not Applicable i

b. Automatsc Actuation Logic Not Applicable Not Applicable -

y

c. Containment Pressure--liigh-liigh $ 2.81 psig i 2.97 psig ,

[

E d. Steam iInw in Iwo Steam lines-- < A funct. ion defined as < A function defined as liigh I: . incident with 1 --Low-Low Vollows: A Ap correspond- iollows: A Ap corresponding DrSteamLinePressure*40w ing to 40% of full steam to 44% of full steam flow flow between 0% and 20% between 0% and 20% load load and then a Ap- and then a Ap increasing increasing linearly to a linearly to a Ap correspond-Ap corresponding to ing to 111.5% of full steam 110% of full steam flow flow at full load at full load.

T,yg 3 540 F T,yg > 538'F 2 600 psig steam ? 580 psig steam line pressure line pressure

5. IUR81NE 1 RIP AND FEEDWATER ISOLATION

a. Steam Genetator Water level-- s /S% of narrow range < 76% of narrow range Instrument span each steam

~

liigh-Iligh '~ instrument span each steam.

ganerator generator h, Aulesnelis Ac M SE** '*$ g,A. Jef. A.

- ) _0

.~

Q% . .: 1 (;w-) -

~

un

' TABLE 3.3-4 (Continued) .,..

a ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS i

E q FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES ro

8. ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS (Continued) *

b. T avgrevents Manual Block of Safety InjectionP-12 1 540*F 3 542*F

c. T,yg Manual Block of Safety Injection, ~'

' Steam Line Isolation, Block Steam j Dump 1 540*F 1 538'F -

M a

i d. Steam Generator Level

y Turbine Trip, Feedwater Isolation ~

) g P-14 (See 5. above)

9. AUTOMATIC SWITCHOVER TO R5 CONTAINMENT SUMP

a. RWST Level - Low 130" from tank base 130" 1 4" from tank base COINCIDENT WITH Containment Sump Level - High 30" above elev. 680' 30" 1 2.5" above elev. 680' AND Safety Injection (See 1 above for all Safety Injection Setpoints/ Allowable Valves)

g. p.s.ealie. Achel;. L.3sc .

g, g. .

N.A.

, , , . tchover of RHR ptap suction from the RWST to containment p s=

1li be employe u level ind 1ABLE. R5 i " Automatic switchove e interim. This note

! ! ll n e fect for a period not to exceed 30 days u ..

Pl

<n

~7T TABLE 3.3-5 (Continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS

6. Steam Flow in Two Steam Lines-High Coincident with Steam Line Pressure-Low

a. Safety Injection (ECCS) i 13.0(.7)/23.0(1) l b. Reactor Trip (from SI) 1 3.0

c. Feedwater Isolation < 8.0(2)

d. Containment Isolation-Phase "A"(3) 18.0(8)/28.0(9)

e. Containment Ventilation Isolation Not Applicable

f. Auxiliary Feedwater Pumps 1 60

g. Essential Raw Cooling Water System 1 65.0(8)/75.0(9)'

h. Steam Line Isolation < 8.0

i. Emergency' Gas Treatment Systen [38.0(9)

7. Containment Pressure--High-Hich

a. Containment Spray < 58.00(9) 65(8)/75(9)

] '

b.

c.

Containment Isolation-Phase "B" Steam Line Isolation

.1 7.0

d. Containment Air Return Fan > 540.0 and i 660

8. Steam Generator Water Level--Hich-High

a. Turbine Trii, , . ..tr -f; 1 2.5

. . b. Feedwater Isolation i 11.0(2)

9. Main Steam Generator Water Level -

Low-Low

a. Motor-driven Auxiliary 1 60.0 Feedwater Pumps (4)

b. Turbine-driven Auxiliary i 60.0 Feedwater Pumps (5)

SEQUOYAH - UNIT 2 3/4 3-31 e

5

[* "jkl ff. 7' ' .

y c o, ,

TABLE 4.3-2 (Continued) .

y .,,' 0yo E. . .;t. .

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION

SURVEILLANCE REQUIREMENTS F,: . .'t?g .

, n: . . .

CHANNEL

)'

P

.",~ 'i. ..

FUNCTIONAL UNIT CHANNEL CHANNEL FUNCTIONAL MODES FOR WHICH SURVEILLANCE IS

'3 CHECK CALIBRATION- TEST

.-4 ..

' REQUIRED N

4) Containment Purge Air S R M 1,2,3,4

' Exhaust Monitor Radio-activity-High

5) Containment Particulate S R -

M 1,2,3,4 1

Activity-High -

4. STEAM LINE ISOLATION

, a. Manual N.A. N. A.

i N R 1,2,3 .

b. R39

[* Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3 M c. Containment Pressure-- S High-High R Q 1,2,3

d. Steam Flow in Two Steam S Lines--High Coincident with R Q 1,2,3 j T -- Lo -Low or Steam Line 1

PN9surew-Low

!' 5. TURBINE TRIP AND FEEDWATER j7 p ISOLATION il i a. Steam Generator Water

l r Level--High-High S R Q 1, 2, 3 l I Ll l e.

b. A to m / A M et. u las k N.A.

,l : . 6. AUXILIARY FEEDWATER N 4-py M(5) h2; 3

, . - a. Manual N.A. N.A.

R 1,2,3 R39

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

%.- \

m TABLE 4.3-2 (Cantfaued} -

E ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRtalENTATION .

S SURVEILLANCE Nt4UINUEntT3 c CNAleEL MODES FOR leiICH 5 -

CHANNEL CHANNEL FUNETIONAL SURVEILLANCE IS

FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED to

! 8. ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS

a. Pressurizer Pressure, N.A. R (2) .

N.A. 1,2,3 P-11

b. T,yg, P-12 N.A R (2) N.A. 1,2,3

, , c. Steam Generator N.A. R (2) N.A. 1, 2 g Level, P-14 -

T -

U

9. AUTOMATIC SWITCHOVER TO CONTAINMENT SUMP

a. RSWT Level - Low S R M 1,2,3,4 COINCIDENT WITH Containment Sump Level - High S R M 1, 2, 3, 4 AND Safety Injection (See 1 above for all Safety Injection Surveillance Requirements) l ? ;? h. Ahmlie 41,,ak 4 5lc. p.g' U] b N' Mb) I;2)3; '{

t n bl l

. G lR

]

p ,

)

5 TABLE 4.3-2 (Continued) -, , , , il 3

i m .

-1 l j ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS g

4

' CNANNEL M00ES FOR WHI e SURVEILLAN' S CHANNEL FUNCTIONAL 5

CHANNEL TEST RE003AD ;

CHECK CALIBRATION - el FUNCTIONAL N

15 y

! OVER T0

9. AUTOMATIC SW CONTAINMENT SUM i

S R -

H 1,2,3,4 ;

a. RSWT Level - Low i

COINCIDENT WITH , , , , )

' Containment Sump Level igh S R 1, 2, 3, 4 ;

e AND Safety Injection (See 1 above for all ty Injection Surveillance Requirements) 1 1 #

w ' -

i l *l 7

5 b -o '.

l D I cs

! I 3

! E a. i

! -R

?a j G2

,9

Note: Manual switchover of RHR pump suction from the RWST to containment sump will be employed untti containment,sunp level indicators are returned OPERABLE.

R5 -

)

1

Automatic switchover is not required GPERABLE during the interim. This note will remain in effect for a period not to exceed 30 days (July 18,1982). ,

F 6 l f

L. . 4 ..1-, - - 4A,. .+ 4 4 m- - r 5 8 ENCLOSURE 2 PROPOSED TECHNICAL SPECIFICATION CHANGES SEQUOYAH NUCLEAR PLANT UNITS 1 AND 2 DOCKET NOS. 50-327 AND 50-328 (TVA-SQN-TS-87-20)

DESCRIPTION AND JUSTIFICATION FOR PROPOSED AMENDMENT TO REACTOR PROTECTION SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 1

I

\

1 1

I

._ _ _ _ . _~_ _ _ _ . _ _ _ _m . ._ __ ____ _ _

t 4

ENCLOSURE 2 Description of Chanae The proposed change will revise the following functions for reactor trip system and engineered safety feature (ESP) actuation system instrumentation:

1. Remove channel calibration requirement for the reactor trip, P-4 function, from Table 4.3-1, " Reactor Trip System Instrumentation Surveillance Requirements."

2. Clarify the channels to trip for manual containment spray and phase "B"

+

isolation in Table 3.3-3, " Engineered Safety Feature Actuation System Instrumentation."

b

3. Remove reactor trip function from high-high steam generator water level signal, Table 3.3-5, " Engineered Safety Features Response Times."

4. Add automatic actuation logic requirement for turbine trip and feedwater isolation and automatic switchover to containment sump and extend time allowed to perform surveillance testing from one hour to two hours.

Additionally, for unit 2 only, a redundant listing of automatic switchover to containment sump will be deleted. An associated footnote, applicable to both units, concerning manual switchover of residual heat removal (RHR) suction from the refueling water storage tank (RWST) to the-containment sump will also be deleted.

I Reason for Chanae

l. The P-4 permissive is derived from the reactor trip breaker position and performs the following functions:

Reactor tripped - actuates turbine trip, closes main feedwater valves on T yg below setpoint, prevents the opening of the main feedwater valves which were closed by a safety injection or high steam j generator water level signal, allows manual block of the automatic reactuation of safety injection.

Reactor not tripped - defeats manual block preventing automatic

.- reactuation of safety injection.

The P-4 contact is a series / parallel set of contacts that provides on-off l continuity to the above functions. A signal to this contact will

! initiate performance of these functions. A channel calibration is not applicable since no setpoint is involved.

l l

V .

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

^

2. The number listed for " channels to. trip" is not accurate as indicated.

The switches for the manual function channels are paired for containment spray and phase "B" isolation. Two switches must be operated simultaneously in order to trip.

3. The high-high steam generator water level signal will not generate a reactor trip. The only safety functions generated by this signal are a turbine trip and feedwater isolation. The listed response time should only apply to the turbine trip.

4. The present requirements for " turbine trip and feedwater isolation" and

" automatic switchover to containment sump" only test the process signal up to the bistable. Af ter the bistable is tripped, a signal is sent to the logic test cabinets where the logic is tested, and a trip is initiated if the logic is there. The proposed change will add the requirement to test the automatic actuation logic.

The applicable action statement for the automatic actuation logic test allows one channel to be bypassed for up to one hour in order to meet surveillance testing requirements. Because of current problems in meeting the one-hour time period, Sequoyah is requesting this time period be extended to two hours.

One purpose of Amendment 18 of the unit 2 technical specifications, issued to TVA by NRC on May 5, 1983, was to revise table 4.3-2 to conform to a complimentary table given in the unit 1 technical specifications.

Because of an oversight that occurred in the preparation of the submittal requesting Amendment 18, a redundant listing of item 9. " Automatic '

Switchover to Containment Sump," was left in table 4.3-2 of the unit 2 technical specifications. The proposed amendment would delete the redundant listing of item 9 in the subject table as it appears on page 38 of the unit 2 technical specifications.

One purpose of Amendment 18 of the unit 1 technical specifications and Amendment 5 for unit 2, issued to TVA by NRC on June 18, 1982, was to i provide a footnote to table 4.3-2 concerning the switchover of RHR l suction from the RWST to the containment sump in the absence of operable a

containment sump level indicators. The footnote was to be in effect for

.- a period not to exceed 30 days from issuance of the requested amendments, or July 18, 1982. The proposed amendment will delete the expired footnote.

Justification for Change

1. The technical specification requirement to perform a channel calibration L for the P-4 interlock is not practical. A channel calibration, as t

- ,,----c - , - ,---

N defined by the technical specifications, shall be the adjustment, as necessary, of the channel output such that-it: responds with necessary range and accuracy to known values of the parameter which the channel

. monitors. ,

, The p-4 interlock performs its designated function when a 1 of 2 logic is present. The channel output is not dependent on any range or accuracy.

As soon as the p-4 contact senses a signal, the channel output is performed. Operability of the channel output is verified by the channel functional test. The proposed change to remove the channel calibration requirement is consistent with the Westinghouse Standard Technical Specifications.

2. The manual actuation logic for containment spray and phase "B" isolation consists of four momentary controls. Actuation will occur only if two associated controls are operated simultaneously. Two controls per set are preferred to prevent inadvertent spray actuation.

The current technical specification numbers for manual actuation are not correct. The proposed change will correctly reflect the number of' controls required for actuation.

!. 3. The ESF system generates a turbine trip and feedwater isolation on l high-high steam generator water level so as to prevent water from j entering the steam lines, resulting in carryover to the turbine. At ,

operations above 50 percent of rated thermal power, once the turbine has been tripped, a reactor trip signal will be generated. Amendment 7 to the SQN unit 1 facility operating license allowed the deletion of a reactor trip on turbine trips for operations below 50 percent of rated thermal power. Thus, a reactor trip does not provide for the protection of the turbine fro;pcarryover into the turbine because of flooding of the steam lines; it shpuld not be listed with the turbine trip in table 3.3-5 as having a required gSF response time. Furthermore, the proposed change is consistent with the same response time requirements to a high-high steam generator water level event as given in the Westinghouse Standard Technical Specifications.

4. The automatic actuation logic test applies various simulated input

-- combinations in conjunction with each possible interlock logic state and verifles the required logic output. This testing is already being

performed. The addition of this requirement to the technical specifications will ensure proper controls are'in place for complete operability verification and will be consistent with other functional units on the same table and the Westinghouse Standard Technical 3

Specifications.

i 4

}

1 4

r --y-- y-- , - - ,,y-r-. g . . , _ . - - - - , . _ . . - - - . . . -- -- .- _ , , --

The applicable action statement for the automatic actuation logic test allows one channel to be bypassed for up to one hour in order to meet surveillance testing requirements. Because of current problems in meeting the one-hour time requirement, Sequoyah is requesting that this time limit be extended to two hours, provided the other associated channel is operable. The Westinghouse Standard Technical Specifications presently allow two hours to perform this testing. Additionally, WCAP 10271, Supplement 2. " Evaluation of Surveillance Frequencies and Out of Service Times for the Engineered Safety Features Actuation System," has proposed extending this time limit to four hours based on results of fault tree reliability and risk analysis. Sequoyah believes that adequate reliability exists for the extended two-hour testing time, provided the other associated channel is operable.

Table 4.3-2 of the unit 2 technical specifications, as it currently exists, has duplicate entries of item 9, " Automatic Switchover to containment Sump." The duplication of the two entries was verified by an item-by-item comparison of the two entries. Therefore, the deletion of the redundant entcy of item 9 in table 4.3-2 as it appears on page 38 of the unit 2 technical specifications will not alter the requirements for channel checks, channel calibrations, or channel functional tests; nor will it change the modes for which surveillance is required.

The associated footnote provided temporary relief to the requirements of item 9 of table 4.3-2. The duration of the relief was to last for 30 days, extending from June 18, 1982, until July 18, 1982. The applicability of this footnote has long since expired, and its deletion will provide for keeping the technical specifications as simple and as free from extraneous and obsolete statements as possible.

I l

l

8 6 ENCLOSURE 3 PROPOSED TECHNICAL SPECIFICATION CHANGES SEQUOYAH NUCLEAR PLANT UNITS 1 AND 2 DOCKET NOS. 50-327 AND 50-328 (TVA-SQN-TS-87-20)

DETERMINATION OF NO SIGNIFICANT HAZARD CONSIDERATIONS FOR PROPOSED AMENDMENT TO REACTOR PROTECTION SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION er 6*

O 4

SIGNIFICANT HAZARDS CONSIDERATIONS Is the probability.of an occurrence or the consequences of an accident previously evaluated in the safety analysis report significantly increased?

1. No. The P-4 interlock performs designated safety functions following a reactor trip. The capability to perform these functions is not dependent on any range or accuracy. Initiation of the safety functions will occur when a 1 of 2 logic is present. Deletion of the P-4 channel calibration will not prevent function capability nor decrease reliability.

2. No. The added words for containment spray and phase "B" isolation more clearly define actuation requirements. Function capability has not been changed nor reliability decreased.

3. No. A reactor trip is not expected to occur directly as n result of high-high steam generator water level. The high-high water level signal will generate a turbine trip which will immediately initiate a reactor trip. Removing the response time for a reactor trip from this function does not prevent timely action for a reactor trip, as other applicable response times for a reactor trip remain in effect.

4. No. The addition of automatic actuation logic testing to the technical specifications is necessary to ensure intended functions assumed in the safety analysis report are reliable. This testing is consistent with other testing requirements in the same table. The extended testing time has been evaluated, and the analysis determined that reliable function operability still exists. The additional testing and increased testing time do not alter the manner in which protection is afforded. Deletion of the redundant surveillance requirement entry and the expired footnote is strictly administrative and does not alter any testing, action, or operating requirements of the plant.

Is the possibility for an accident of a new or different type than evaluated previously in the safety analysis report created?

1. No. Deletion of the p-4 channel calibration removes an inappropriate test requirement. The channel functional testing will still be performed in a manner to ensure equipment reliability.

2. No. The proposed change only affects the technical specifications by adding clarification to existing requirements. The mechanism to trip the channels is still the same. No modifications or procedural changes are

necessary.

3

3. No. The proposed deletion will not result in a change in which reactor

trip protection is provided. The manner in which a turbine trip and I

subsequent reactor trip resulting from a high-high steam generator water l

level signal would occur has not been changed.

4

}

l l

2

.4. No. The proposed changes will not require any modifications or alter any testing, action, or coerating requirements of the plant. Existing testing techniques wil2 be used to satisfy the additional requirements; and present testing, wt.are times have been extended, will be performed the same way. The two items being deleted affect only the technical specifications and are strictly administrative.

Is the margin of safety significantly reduced?

1. No. The margin of safety has not been changed. Function operability and reliability have not been affected.

2. No. The margin of safety has not been changed. Clarification has been added to the technical specifications to avoid any confusion in necessary action required for channel trip.

3. No. The margin of safety has not been changed. The proposed change makes a correction to an inappropriate response time requirement.

4. No. The administt'ative changes will not affect the margin of safety.

The additional testing requirements will provide additional assurance of equipment operability. The extended testing time is based on fault tree reliability and risk analysis and will not significantly reduce the margin of safety.

.- e -.er, --- , , . , , . _ , - - . - . . - - , - - . - _ , . - . . - . , , ._ . , , ,.~._.-,__,m_.,-~__,-,._-._...,.,,v

ML20214M882

Text

Navigation menu

Search