Text

Proposed Tech Specs Reflecting Extension of Certain 18-month Frequency Surveillances to Refueling Interval
	ML20084R017
Person / Time
Site:	Calvert Cliffs
Issue date:	06/06/1995
From:	; BALTIMORE GAS & ELECTRIC CO.
To:	;
Shared Package
ML20084R013	List: ML20084R011; ML20084R017;
References
	NUDOCS 9506090159
	Download: ML20084R017 (33)
	v • d • e

7.

i 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTIVE INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.1.1 As a minimum, the reactor protective instrumentation channels and bypasses of Table 3.3-1 shall be OPERABLE. l APPLICABILITY: As shown in Table 3.3-1.

ACTION: As shown in Table 3.3-1.

SURVEILLANCE REQUIREMENTS 4.3.1.1.1 Each reactor protective instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the MODES and at the frequencies shown in Table 4.3-1.

4.3.1.1.2 The logic for the bypasses shall be demonstrated OPERABLE prior to each reactor STARTUP unless perfonned during the preceding 92 days. The total bypass function shall be demonstrated OPERABLE at least once per R, Git,3 pe%I -1G seaths during CHANNEL CALIBRATION testing of each channel affected by bypass operation.

4.3.1.1.3 The REACTOR TRIP SYSTEM RESPONSE TIME of each reactor trip function

shall be demonstrated to be within its limit at least once per l

%d.3 Liew.I -13 = nth . Each test shall include at least one channel per function such that all channels are tested at least once every N -tir IS = nth; where N is the total number of redundant channels in a specific 7 reactor trip function as shown in the " Total No. of Channels" columnl of Table 3.3-1.

i

/

fxfakg lderals l

l 9506090159 950606 PDR ADOCK 0500o317 P PDR Neutron detectors are exempt from response time testing. l l CALVERT CLIFFS - UNIT 1 3/4 3-1 Amendment No. 184 l

1

g TABLE 4.3-1 R r- =

REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE REQUIREMENTS w b CNANNEL MODES IN WNICH ;

7 CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED k h 1. Manual Reactor Trip NA NA S/UIll NA Z 2. Power Level - High Ei

~ *

a. Nuclear Power S D(2), M(3), Q(5) Q 1, 2 l

b. AT Power S D*),*

I I 2 Q 1 l

3. Reactor Coolant Flow - Low S 4 Re k k 3t,Je mi Q 1, 2 l R

=

4. Pressurizer Pressure - High S -R Rd 124 3I,& %g Q 1, 2 l w 5. Containment Pressure - High S tM412 3 rJe,,i Q 1, 2 l

6. Steam Generator Pressure - Low 4 Rehh 3 4%1 Q S 1, 2 l

7. Steam Generator Water Level - S Low 44 M nk 31.de m l Q 1, 2 l

8. Axial Flux Offset S -4 Re k ig IAe~.1 Q 1 l

9. a. Thermal Margin / Low Pressure S 4Rekk 3 Lket Q 1, 2 l 5

g

b. Steam Generator Pressure Difference - High S Mefaly Lbl Q 1, 2 l k 10. Loss of Load NA NA S/U(1) NA

.E

, w

. a

- - - - - - - , - - - ,_- --e- -- -- , ..--- _ _ - . , - - - , - - - _ r - ___ __--_ _ _ _ _ _ _

g TABLE 4.3-1 (Continued) -

G R g ?

w REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE REQUIREMENTS b CHANNEL MODES IN WHICH w q CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE "'

'd FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED E h 11. Wide Range Logarithmic Neutron Flux S RQ)y g ,g S/UIII 1, 2 q Monitor and , 3, 4, 5 I g

12. Reactor Protection System Logic Q and S/UII) *

- NA NA 1, 2 Matrices l

13. Reactor Protection System Logic NA NA Q and S/UIll 1, 2 Matrix Relays l

14. Reactor Trip Breakers NA NA M 1, 2 and

w w

l I

iir a

a

.F M

3/4.3 INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2.1 The Engineered Safety Feature Actuation System (ESFAS) instrumentation channels and bypasses shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-4. l ,

APPLICABILITY: As shown in Table 3.3-3.

ACTION:

a. With an ESFAS instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3-4, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint value.

b. With an ESFAS instrumentation channel inoperable, take the ACTION shown in Table 3.3-3.

SURVEILLANCE REQUIREMENTS 4.3.2.1.1 Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the MODES and at the frequencies shown in Table 4.3-2.

4.3.2.1.2 The logic for the bypasses shall be demonstrated OPERABLE during the at power CHANNEL FUNCTIONAL TEST of channels affected by bypass operation. The total bypass function shall be demonstrated OPERABLE at least once per 10 yenths during CHANNEL CALIBRATION testing of each channel affected by bypassl operation. ;

-Acklty Inhal 4.3.2.1.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per y 4 Io h l 10 wenths. Each test shall include at least one channel per function such that all channels are tested at least once every N ti:^: IS :pr.th:; where N is the total number of redundant channels in a specific ESFAS lfunction as shown in the " Total No. of Channels" Column of Table 3.3-3.

ReklA 3 L+< mis I

CALVERT CLIFFS - UNIT 1 3/4 3-9 Amendment No. 184 ,

l

g TABLE 4.3-2 G R g ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS w b CHANNEL MODES IN WHICH q CHANNEL CHANNEL

FUNCIML UNIT CHECK CALIBRATION FUNCTIONAL.

TEST SURVEILLANCE REQUIRED g

b

h

1. SAFETY INJECTION (SIAS) y

~

a. Manual (Trip buttons)

b. Containment Pressure - High NA S

NA gj.

-& u ,3

-R #Ni NA 1, 2, 3 Q

c. Pressurizer Pressure - Low S 1, 2, 3

d. Automatic Actuation Logic NA -R- qu,,i wNAr*+e Mll)g)(3) d 1, 2, 3

2. CONTAINMENT SPRAY (CSAS)

a. Manual (Trip buttons) id b. Containment Pressure - High NA NA it-(k"M NA S -ft Ad"j; p 1, 2, 3 l 5 c. Automatic Actuation Logic NA NA Mil g(8) 1, 2, 3

3. CONTAINMENT ISOLATION (CIS)'

a. Manual CIS (Trip buttons) NA NA -ft-!h)IP NA

b. Containment Pressure - High S R Md ~ 1,2,3 l

c. Automatic Actuation Logic NA NA ***'h M(1g(*) 1, 2, 3 N

-a m

r+

af t

5 w

. e k

~

g TABLE 4.3-2 (Continued)

G R*

g ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS U b CHANNEL q CHANNEL CHANNEL FUNCTIONAL MODES IN WHICH FUNCTIONAL UNIT CHECK CALIBRATION SURVEILLAMCE E TEST REQUIRED i5 C a:

ii 4. Y w MAIN STEAM LINE ISOLATION (SGIS) d

'" o

a. Manual SGIS (MSIV Hand Switches and Feed Head Isolation Hand NA NA M"**M NA Switches) gg j,

b. Steam Generator Pressure - Low S -R u,y,,,/ 1, 2, 3

c. Automatic Actuation Logic NA NA MUgN 1,2,3 l

g 5. CONTAINMENT SUMP RECIRCULATION (RAS) t' a. Manual RAS (Trip Buttons) NA NA

M"I*3 g b. Refueling Water Tank - Low *^I'*

NA

c. Automatic Actuation Logic NA NA

-R-NA

/ Mg) 1, 2, 3 1, 2, 3 l

6. CONTAINMENT PURGE VALVES ISOLATION I

a. Manual (Purge Valve Control NA NA -R-S, NA Switches) b.

Containment Radiation - High Area

[ Monitor S

4 M'*l '*3 Q 6** l i

a n

w e

g TABLE 4.3-2 (Continued) R G

g ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS U w

n E i C CHAlNIEL MODES IN WHICH Q q CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE "'

{

c FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED !

{

7. LOSS OF POWER y

a. 4.16 kv Emergency Bus Undervoltage NA

A* f Q 1, 2, 3 l (Loss of Voltage)

b. 4.16 ky Emergency Bus Undervoltage NA -R- W hs Q 1, 2, 3 l (Degraded Voltage) L+ervat

8. CVCS ISOLATION West Penetration Room / Letdown NA -R du 1, 2, 3, 4 Q

Y Heat Exchanger Room Pressure - High L*^'*Sl l U ,

9. AUXILIARY FEEDWATER

(<fal.k

a. Manual (Trip Buttons) NA NA g i,

L+,%3 NA ;

b. Steam Generator Level - Low S 1t nw,r[,,S Q 1, 2, 3

c. Steam Generator AP - High S 1,2,3 N

d. Automatic Actuation Logic NA *nd,J NA L3, L-MgI 1, 2, 3 ,

a

.F W

- -- -- - ~

3/4.3 INSTRUMENTATION -

TABLE 4.3-2 (Continued) ,

TABLE NOTATION Containment isolation of non-essential penetrations 1s also initiated j by SIAS (functional units 1.a and 1.c). .

Must be OPERABLE only in M0DE 6 when the valves are required CPERABLE and they are open. l (1) The logic circuits shall be tested manually at least once per 31 days.

(2) SIAS logic circuits A-10 and B-10 shall be tested monthly with the l exception of the Safety Injection Tank isolation valves. The SIAS logic circuits for these valves are exempted from testing during operation; however, these logic circuits shall be tested at least once per-10 m;nthe during shutdown.

Aebl.k3 L+erwl (3) SIAS logic circuits A-5, and B-5 are exempted from testing during operation; however, these logic circuits shall be tested at least once per 10 mc;ths during shutdown.

AcLelA 3 Lte,wl (4) CIS logic circuits A-5 and B-5 are exempted from testing during operation; however, these logic circuits shall be tested at least once per 18 = nthe during shutdown.

Acksh3 L+eral (5) SGIS logic circuits A-1 and B-1 are exempted from testing during operation; however, these logic circuits shall be tested at least once per -10 ;caths during shutdown.

4,GIA 3 Ide, val (6) CSAS logic circuits A-3 and B-3 are exempted from testing during operation; however, these logic circuits shall be tested at least once per le ;;nths during shutdown. ,

Rehek g L termi I

l CALVERT CLIFFS - UNIT 1 3/4 3-22 Amendment No. 193

g . TABLE 4.3-3 C; R

?

g RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS w b CNANNEL MODES IN WNICM q CHANNEL CNANNEL FUNCTIONAL

SURVEILUUlCE g INSTRUMENT CHECK CALIBRATION TEST

' REQUIRED m c- 1. AREA MONITORS "I 5 >

a. Containment d

~ E

1. Purge & Exhaust Isolation A la S it y,Ca

, d M 6

b. Containment Area High Range S -R- Ack b g M 1, 2, 3, & 4

2. PROCESS MONITORS **'

R

a. Containment M i. Gaseous Activity a) RCS Leakage Detection S R M 1, 2, 3, & 4

11. Particulate Activity a) RCS Leakage Detection S R M 1, 2, 3, & 4 k b. Noble Gas Effluent Monitors E

y i. Main Vent Wide Range S R M 1, 2, 3, & 4

{

g 11. Main Steam Header S R M 1, 2, 3, & 4 I

.E

3/4.3 INSTRUMENTATION l

TABLE 4.3-6 REMOTE SNUTDOWN MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CNANNEL CNANNEL l INSTRUMENT CNECK CALIBRATION !

1. Wide Range Neutron Flux M NA !

2. Reactor Trip Breaker Indication M NA i

3. Rchh3 Reactor Coolant Cold Leg Temperature M -R u,.yi ;

4. Pressurizer Pressure M

-R-h([1]

5. Pressurizer Level M A*M*h5

-R Ltenil

6. Steam Generator Level (Wide Range) M -R Rc+41%

Lte,wt

7. Steam Generator Pressure M

-R-Lbw g,hlta[

l l

1 l

CALVERT CLIFFS - UNIT 1 3/4 3-32 Amendment No. 199 l

Q TABLE 4.3-10 t*

G g POST-ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE RE0UIREMENTS 5d b CHAINIEL q INSTRUMENT CHECK CIUUNIEL 8'

CALIBRATI0ll

1. Containment Pressure 4 wl.w3 E i

M 4 n, % :

E 2. Wide Range Logarithmic Neutron Flux Monitor G M MA w

3. Reactor Coolant Outlet Temperature <<GL%3 M -R- rote %I E 4.

5.

Pressurizer Pressure Pressurizer Level M

+hD

6. Steam Generator Pressure M

4 fAD g 7. Steam Generator Level (Wide Range)

M 4-ND M -4 $13, y 8. Auxiliary Feedwater Flow Rate M 4 R & kas M 9. RCS Subcooled Margin Monitor Liems M -4 A.614 3

10. PORV/ Safety Valve Acoustic Monitor NA ' -A 4.uk n u .t3

11. PORY Solenoid Power Indication NA NA

12. Feedwater F1ow

13. Containment Water Level (Wide Range)

M -R-$h g M 4- RefML+e~%

.1

, 14. Reactor Vessel Water level M NA k 15. Core Exit Therwocouple System M R.

A E

The performance of a CIUUNIEL CALIBRATI0ll operation exempts the Core Exit Thermocouple but 3 includes all electronic components. The Core Exit Therwocouple shall be calibrated prior to t

installation in the reactor core.

~_ __ , _ w - _ _ _ _ _ _ . _ _ _ _ _r__ __ __ _ _ _ . _ _ _ _ _ _ _ ___

. = - .. - _ _-

3/4.4 It.[A_CTOR C0OLANT SYSTEM SURVEILLANCE REQUIREMENTS 4.4.3.1 Each PORV shall be demonstrated OPERABLE:

a. At least once per 31 days by perfomance of a CNANNEL FUNCTIONAL TEST, in accordance with Table 4.3-1, Item 4.

b. At least once per 10 sathe- by performance of a CNANNEL CALIBRATION. A&elA3 24tc,vd 4.4.3.2 Each block valve shall be demonstrated OPERABLE at least once per 92 days by operating the valve through one complete cycle of full travel unless the block valve is closed to meet the requirements of Action a, b, or c in Specification 3.4.3.

CALVEP.T CLIFFS - UNIT 1 3/4 4-8 Amendment No. 188

3/4.4 REACTOR C0OLANT SYSTEM SURVEILUWICE REQUIREMENTS 4.4.6.1 The Leakage Detection Systems shall be demonstrated OPERABLE by:

, a. Containment Atmosphere Gaseous and Particulate Monitoring l

Systems-perfonnance of CIUWHIEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST at the frequencies specified in Table 4.3-3, and

b. Containment Sump Level Alarm System-perfonnance of CHANNEL CALIBRATION at least once per IS - .the.

Ref5 3Interv<\

l l

I l

CALVERT CLIFFS - UNIT 1 3/4 4-18 Amendment No. 188 l

3/4.4 REACTOR COOLANT SYSTEM l l

LIMITING CONDITION FOR OPERATION (Continued)

2. Verify the excessive flow condition did not raise pressure l above the maximum allowable pressure for the given RCS '

temperature on Figure 3.4.9-1 or Figure 3.4.9-2. l

3. If a pressure limit was exceeded, take action in accordance with Specification 3.4.9.1.

h. The provisions of Specification 3.0.4 are not appitcable. l SURVEILLANCE REQUIREMENTS 4.4.9.3.1 Each PORV shall be demonstrated OPERABLE by:

a. Perfomance of a CHANNEL FUNCTIONAL TEST on the PORY actuation .

channel, but excluding valve operation, within 31 days prior to entering a condition in which the PORY is required OPERABLE and at least once per 31 days thereafter when the PORY is required OPERABLE.

b. Perfomance of a CHANNEL CALIBRATION on the PORV actuation channel at least once per 18 :=ths.

Ael.<thg1hmt

c. Verifying the PORY block valve is open at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months l when the PORV is being used for overpressure protection..

d. Testing in accordance with the inservice test requirements pursuant to Specification 4.0.5.

4.4.9.3.2 The RCS vent (s) shall be verified to be open at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months when the vent (s) is being used for overpressure protection.

4.4.9.3.3 All high pressure safety injection pumps, except the above OPERABLE pump, shall be demonstrated inoperable at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the motor circuit breakers have been removed from their electrical power supply circuits or by verifying their discharge valves are locked shut. The automatic opening feature of the high pressure safety injection loop MOVs shall be verified disabled at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The above OPERABLE pump shall be verified to have its handswitch in pull-to-lock at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Except when the vent pathway is locked, sealed, or otherwise secured in the open position, then verify these vent pathways open at least '

once per 31 days.

CALVERT CLIFFS - UNIT 1 3/4 4-35 Amendment No. 188 l

ATTACIIMENT (2)

UNIT 2 TECIINICAL SPECIFICATION MARKED-UP PAGES

]

l l

l

3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTIVE INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.1.1 As a minimum, the reactor protective instrumentation channels and bypasses of Table 3.3-1 shall be OPERABLE. l APPLICABILITY: As shown in Table 3.3-1.

ACTION: As shown in Table 3.3-1.

SURVEILLANCE REQUIREMENTS 4.3.1.1.1 Each reactor protective instrumentation channel shall be demonstrated OPERABLE by the perfomance of the CHANNEL CHECK, CHANNEL CALIBRATION and CNANNEL FUNCTIONAL TEST operations during the MODES and at the frequencies shown in Table 4.3-1.

4.3.1.1.2 The logic for the bypasses shall be demonstrated OPERABLE prior to each reactor STARTUP unless perfomed during the preceding 92 days. The total bypass function shall be demonstrated OPERABLE at least once per (J,.lc y Liemt 48 ;;.,tts during CHANNEL CALIBRATION testing of each channel affected by bypass operation.

The REACTOR TRIP SYSTEM RESPONSE TIME of each reactor trip 4.3.1.1.}

function s hall be demonstrated to be within its limit at least once per l Rd,dc ) L4 cal - 18 se .the. Each test shall include at least one channel per function such that all channels are tested at least once every N tiscs 10 imidh5 where N is the total number of redundant channels in a specific reactor trip function as shown in the " Total No. of Channels" column f Table 3.3-1.

bbby Ldeals l

l Neutron detectors are exempt from response time testing. l CALVERT CLIFFS - UNIT 2 3/4 3-1 Amendment No. 161

l g TABLE 4.3-1 R G ^

g REACTOR PROTECTIVE INSTRUNENTATION SURVEILLANCE REQUIREMENTS <d b CHANNEL D DES IN WHICH "4 i y CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE g

" FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED m h 1. Manual Reactor Trip NA NA S/Uill NA h

Z 2. Power Level - High y N

a. Nuclear Power S D(2), M(3), Q(5) Q 1, 2 l

b. AT Power S D("),t fj h Q 1 l

3. Reactor Coolant Flow - Low S. -R-Rekk 3 L tc ~ l Q 1, 2 l R 4. Pressurizer Pressure - High S *(ekh 3 Lhml Q 1, 2 l a

y 5. Containment Pressure - High S

ReGeh3 Ltemi Q 1, 2 l

6. Steam Generator Pressure - Low S -R Rek b3 IAe+.1 Q 1, 2 l

7. Steam Generator Water Level - -R- Rebh 3 Lt<%l Q S 1, 2 l Low

8. Axial Flux Offset S -R-Rebb j Idhml Q 1 l

9. a. Thennal Margin / Low Pressure S

Ref d3 Ide=1 Q 1, 2 l N

@ b. Steam Generator Pressure S

Kef.<h3 feh**I Q 1, 2 l

& Difference - High k 10. Loss of Load NA NA S/U(1) NA E

o S

g TABLE 4.3-1 (Continued) R r- =

REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE REQUIREMENTS w b CHANNEL MODES IN WHICH q CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

" FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED k""

b

11. Wide Range Logarithmic Neutron Flux S -M5) S/U(1) 1, 2 h Monitor "j and , 3, 4, 5 y m 12. Reactor Protection System Logic NA NA 1, 2

Q and S/U(1) l Matrices

13. Reactor Protection System Logic NA NA Q and S/U(1) 1, 2 [

Matrix Relays

14. Reactor Trip Breakers NA NA M 1, 2 and

R.

W i'T a

1 8 e

O

4

3/4.3 INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2.1 The Engineered Safety Feature Actuation System (ESFAS) instrumentation channels and bypasses shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-4. l APPLICABILITY: As shown in Table 3.3-3.

ACTION:

a. With an ESFAS instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3-4, declare the channel inoperable and apply the I applicable ACTION requirement of Table 3.3-3 until the channel is l restored to OPERABLE status with the trip setpoint adjusted '

consistent with the Trip Setpoint value.

b. With an ESFAS instrumentation channel inoperable, take the ACTION shown in Table 3.3-3.

SURVEILLANCE REQUIREMENTS 4.3.2.1.1 Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the perfomance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the MODES and at the frequencies shown in Table 4.3-2.

4.3.2.1.2 The logic for the bypasses shall be demonstrated OPERABLE during I the at power CHANNEL FUNCTIONAL TEST of channels affected by bypass l operation. The total bypass function shall be demonstrated OPERABLE at least once per le affectedbybypass(nonthsduringCHANNELCALIBRATIONtesting operation. '

Ref A I dcral 4.3.2.1.3 TheENGINEEREDkAFETYFEATURESRESPONSETIMEofeachESFAS function shall be demonstrated to be within the limit at least once per bbk 3Ideml 18 -^aths. Each test shall include at least one channel per function such that all channels are tested at least once every N .. ...- __ ._..... where N is the total number of redundant channels in a specific ESFAS' function as shown in the " Total No. of Channels" Column of Table 3.3-3.

Rebdb Lderals CALVERT CLIFFS - UNIT 2 3/4 3-9 Amendment No. 161

g TABLE 4.3-2 R r-

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS E' b CHANNEL MODES IN WHICH q

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED k c =

! 1. SAFETY INJECTION (SIAS) y

a. Manual (Trip buttons) NA NA g,gicy -R- { NA

b. Containment Pressure - High S 4- Li,% Q 1, 2, 3

c. Pressurizer Pressure - Low S 1, 2, 3 illg)(3)

d. Automatic Actuation Logic NA -R- w ie.21 NA Ide~ M 1, 2, 3

2. CONTAINMENT SPRAY (CSAS)

a. Manual (Trip buttons) NA NA -R " **I

^S NA y b. Containment Pressure - High S -R Ed'h MIlg(8) 1, 2, 3 l 3 c. Automatic Actuation Logic NA NA MWI 1, 2, 3

3. CONTAINMENT ISOLATION (CIS)'

a.

b.

c.

Manual CIS (Trip buttons)

Containment Pressure - High Automatic Actuation Logic NA S

NA

-R gddg%

-R-Mil g(*)

) NA 1, 2, 3 l NA NA M**3 1, 2, 3 E

B a.

a

.F o

4 0

l g TABLE 4.3-2 (Continued) l G R I g ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUNENTATION SURVEILLANCE REQUIREMENTS U w

b CHANNEL MODES IN WNICH q" CNANNEL CNANNEL FUNCTIONAL SURVEILLANCE "

FUNCTIONAL UNIT CNECK CALIBRATION TEST

' REQUIRED !

e i'i.

n 5 4. MAIN STEAM LINE ISOLATION (SGIS) y

" =

a. Manual SGIS (MSIV Hand Switches NA NA -R tee d'S NA I

and Feed Head Isolation Hand Switches)

b. Steam Generator Pressure - Low S t-dy g,y 1, 2, 3

c. MC g(5) l Automatic Actuation Logic NA NA 1, 2, 3 g 5. CONTAINMENT SUMP RECIRCULATION (RAS) y a. Manual RAS (Trip Buttons) s.a.k B b. Refueling Water Tank - Low NA NA 4 Ld NA

c. Automatic Actuation Logic NA NA NA Q

-R3g^f MgI i, 2, 3 1,2,3 l

6. CONTAINMENT PURGE VALVES ISOLATION

a. Manual (Purge Valve Control NA NA -R- y N Switches) 6,A,

b. Containment Radiation - High g Q l k Area Monitor S

4 h*l 3 E

a

.F o \

l

. . I

1 pm I

g TABLE 4.3-2 (Continued) R G P g ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS (d b CHANNEL MODES IN WHICH Ei y CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE E

^

FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED i i5i

=

C Y

1 g 7. LOSS OF POWER y

I

a. 4.16 kV Emergency Bus Undervoltage WL-

l (Loss of Voltage)

NA tny, 'Sg Q 1,2,3 l

b. 4.16 kv Emergency Bus Undervoltage NA -R Md L'*S Q 1, 2, 3 Rem! l (Degraded Voltage)

8. CVCS ISOLATION West Penetration Room / Letdown NA -e M'~'I5 Q 1, 2, 3, 4 l 7 Heat Exchanger Room Pressure - High U

9. AUXILIARY FEEDWATER

a. Manual (Trip Buttons) teixL'<3 NA NA g,h h -R nyt NA

b. Steam Generator Level - Low S -R Ltew#1 0 1, 2, 3

c. Steam Generator AP - High S Nef41 1,2,3 E

d. Automatic Actuation Logic NA NA Lwd.x Mg) 1, 2, 3 a

.I O

O

. . l

8 3/4.3 INSTWUMENTATION -

TABLE 4.3-2 (Continued) -

TABLE NOTATION Containment isolation of non-essential penetrations is also initiated by SIAS (functional units 1.a and 1.c).

Must be OPERABLE only in M0DE 6 when the valves are required OPERABLE and they are open.

II) ~ u ogic circuits shall be tested manually at least once per 31 days.

(2) SIAS logic circuits A-10 and B-10 shall be tested monthly with the l exception of the Safety Injection Tank isolation valves. The SIAS logic circuits for these valves are exempted from testing during operation; however, these logic circuits shall be tested at least once per 10 we..us during shutdown.

(3)

RMn14 ems SIAS logic circuits A-5 and B-5 are exempted from testing during operation; however, these logic circuits shall be tested at least once per is : nth: during shutdown.

fg

Aebh3 Ltemt CIS logic circuits A-5 and B-5 are exempted from testing during operation; however, these logic circuits shall be tested at least once per " ^" during shutdown.

W (chh3 Lte~ !

SGIS logic circuits A-1 and B-1 are exempted from testing during j operation; however, these logic circuits shall be tested at least once per 10 ae..t b during shutdown.

RchlA 2A ~41 (6) CSAS logic cfrcuits A-3 and B-3 are exempted from testing during i operation; however, these logic circuits shall be tested at least once per 18 ,0nths during shutdown.

AcfA.g Lteml l

i l

CALVERT CLIFFS - UNIT 2 3/4 3-22 Amer.dment No. 170

. 1 1

y TABLE 4.3-3 w 9 RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS 'w c,

C CHANNEL MODES IN WHICH E CHANNEL CHANNEL FUNCTIONAL q INSTRUMENT CHECK CALIBRATION SURVEILLANCE Q TEST REQUIRED vi

. 1.

E AREA MONITORS E e >

a. Containment

] y

i. Purge & Exhaust Isolation S -R- M

} 6

b. Containment Area High Range S -R 44lt=3 M 1, 2, 3, & 4

2. PROCESS MONITORS g a. Containment

i. Gaseous Activity

{

cn a) RCS Leakage Detection S R M 1, 2, 3, & 4

11. Particulate Activity a) RCS Leakage Detection S R M 1, 2, 3, & 4

b. Noble Gas Effluent Monitors g

E. i. Main Vent Wide Range S R M 1, 2, 3, & 4 R

5 11. Main Steam Header S R M 1, 2, 3, & 4 5

N g .

w. m _ -__ _-_m______ m_m._ _ _ _ _ _ ..m_-______m- _ _ _ - - _ _ _ . . _ _ _ - -

._.s _ m _ _ - . _

3/4.3 INSTRUMENTATION TABLE 4.3-6 ,

REMOTE SHUTDOWN MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL INSTRUMENT .CHfCK CALIBRATION

1. Wide Range Neutron Flux h NA

2. Reactor Trip Breaker Indication M NA

3. Reactor Coolant Cold Leg Temperature M RcLel3

-R- Lte,v4

4. Pressurizer Pressure Wl:

M -R L w,.,21

5. Pressurizer Level M 4b r

6. Steam Generator Level M 41 #g 3

7. Steam Generator Pressure M -R.Ref4L'3 Iate % l CALVERT CLIFFS - UNIT 2 3/4 3-32 Amendment No. 176 l

i Q TABLE 4.3-10 E R g P POST-ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS w b CHANNEL INSTRUMENT CHANNEL Q* CHECK CALIBRATION ""

. 1. Containment Pressure (< w E ;

M -R-I.+,rd l l E 2. Wide Range Logarithmic Neutron Flux Monitor M NA -4

3. Reactor Coolant Outlet Temperature M -R- L e E

4. Pressurizer Pressure M -R,$*hh

5. Pressurizer Level M -R- $,D 6.

R 7.

Steam Generator Pressure Steam Generator Level (Wide Range)

M

+$D h 8. Auxiliary Feedwater Flow Rate M

4M M 9. RCS Subcooled Margin Monitor M -4j%

10. PORV/ Safety Valve Acoustic Monitor M tMg NA -R- p D

11. PORY Solenoid Power Indication NA NA

12. Feedwater F1ow

13. Containment Water Level (Wide Range)

M t/h #

g M t(Dg

14. Reactor Vessel Water Level M NA k 15. Cac Exit Themocouple System M R*

A

= ,

The perfomance of a CHANNEL CALIBRATION operation exempts the Core Exit Thermocouple but M includes all electronic components. The Core Exit Themocouple shall be calibrated prior to installation in the reactor core.

\

l 3/4.4 REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS 4.4.3.1 Each PORY shall be demonstrated OPERABLE:

a. At least once per 31 days by perfonnance of a CHANNEL FUNCTIONAL TEST, in accordance with Table 4.3-1. Item 4.

b. At least once per -18 ;r,ths by perfonnance of a CHANNEL CALIBRATION. Rd4% Meu.l 4.4.3.2 Each block valve shall be demonstrated OPERABLE at least once per 92 days by operating the valve through one complete cycle of full travel unless the block valve is closed to meet the requirements of Action a, b, or c in Specification 3.4.3.

t I

CALVERT CLIFFS - UNIT 2 3/4 4-8 Amendment No. 165 i

ll3/4.4 REACTOR C00UUf7 SYSTEM SURVEILLANCE REQUIREMENTS 4.4.6.1 The Leakage Detection Systems shall be demonstrattd 0PERABLE by:

a. Containment Atmosphere Gaseous and Particulate tionitoring Systems-perfomance of CHANNEL CHECK. CHANNEL CALIBRATION and CHAlplEL FUNCTIONAL TEST at the frequencies specified in I Table 4.3-3, and

b. Containment Sump Level Alam System-performance of CHANNEL CALIBRATION at least once per IS m.th. l Rc6 A3 .hte<<*l !

i i

l CALVERT CLIFFS - UNIT 2 3/4 4-18 Amendment No. 165 l

t 3/4.4 REACTOR COOLANT SYSTEM LIMITING CONDITION FOR OPERATION (Continued) j

2. Verify the excessive flow condition did not raise pressure above the maximum allowable pressure for the given RCS temperature on Figure 3.4.9-1 or Figure 3.4.9-2.

3. If a pressure limit was exceeded, take action in accordance >

with Specification 3.4.9.1. ,

h. The provisions of Specification 3.0.4 are not applicable. l

' i SURVEILLANCE REQUIREMENTS 4.4.9.3.1 Each PORV shall be demonstrated OPERABLE by:

a. Performance of a CHANNEL FUNCTIONAL TEST on the PORV actuation channel, but excluding valve operation, within 31 days prior to entering a condition in which the PORY is required OPERABLE and at least once per 31 days thereafter when the PORV is required OPERABLE.

b. Perfonnance of a CHANNEL CALIBRATION on the PORY actuation :

channel at least once per 10 maths. I ReblA 3 Lhl ,

c. Verifying the PORY block valve is open at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months l l when the PORY is being used for overpressure protection.

d. Testing in accordance with the inservice test requirements pursuant to Specification 4.0.5.

4.4.9.3.2 The RCS vent (s) shall be verified to be open at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

when the vent (s) is being used for overpressuie protection.

4.4.9.3.3 All high pressure safety injection pumps, except the above OPERABLE pump, shall be demonstrated inoperable at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

by verifying that the motor circuit breakers have been removed from their i electrical power supply circuits or by verifying their discharge valves are locked shut. The automatic opening feature of the high pressure safety injection loop MOVs shall be verified disabled at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The above OPERABLE pump shall be verified to have its handswitch in pull-to-lock at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Except when the vent pathway is locked, sealed, or otherwise secured in the open position, then verify these vent pathways open at least once per 31 days.

CALVERT CLIFFS - UNIT 2 3/4 4-35 Amendment No. 165

~

ATTACIIMENT (3)

INDEX SECTION PAGE #

DESCRIPTION . . .. .. .1 BACKGROUND . . .2 A. RPS Instruments (Technical Specification Table 4.3-1). . .2

1. Power Level - High, AT Power (Table Item 2.b) . .2

2. Reactor Coolant Flow - Low (Table Item 3) . . . .2

3. Pressurizer Pressure - High (Table item 4) . .. . . . .3

4. Containment Pressure - High (Table Item 5) . ... .. .3

5. Steam Generator Pressure - Low (Table item 6) . . . .3

6. Steam Generator Water Level - Low (Table Item 7).. .3

7. Axial Flux Offset (Table item 8) . .3

8. TM/LP (Table item 9.a).. . .3

9. Steam Generator Pressure Difference - High (ASGT Protection Trip.. .4 Function)(Table item 9.b)

10. Wide Range Logarithmic Neutron Flux Monitor Signal Rate of Change.. . . .4 of Power- High (Table Item 11)

B. RPS Instrument Total Bypass Functions (Technical Specification 4.3.1.1.2).. ,.4

1. Zero Power Mode Bypass for Reactor Coolant Flow - Low, TM/LP and.. .4 Steam Generator Differential Pressure Trips

2. Low Steam Generator Pressure Trip Bypass._ .4

3. Axial Flux Tilt Trip Bypass . .5

4. Wide Range Logarithmic Neutron Flux Monitor Signal Rate of.. .5 Change of Power - High C. RPS Reactor Trip Response (Technical Specification 4.3.1.1.3). .5 D. ESFAS Instruments (Technical Specification Table 4.3-2) . . . .5

1. SIAS (Table item 1.b and .c, Table Notation item 2 and 3). .5

2. CSAS (Table Item 2.b, Table Notation Item 6). . .5

3. CIS (Table item 3.b, Table Notation item 4).. .6

4. Main Steam Line Isolation (Table item 4.b, Table Notation item 5) . .6 l

5. RAS (Table item 5.b).. . .6

6. Containment Purge Valve Isolation Signal (CRS) (Table item 6.b).. .6 l 1

l J

ATTACIIMENT (3)

INDEX i

SECTION PAGE #

7. Loss Of Power - 4.16 kV Bus Undervoltage Signal (Table item 7.a and .b). .6

8. CVCIS (Table Item 8).. . . .7

9. AFW (Table Item 9.b and .c).. . .7 l

l E. ESFAS Manual Trip Buttons (Technical Specification Table 4.3-2, . .7 Items la,2a,3a,4a, Sa,6a, and 9a)

F. ESFAS Instmment Total Bypass Functions (Technical Specification 4.3.2.1.2). .7

1. SIAS Block, Pressurizer Pressure - Low. .7

2. SGIS Block, Steam Generator Pressure - Low. .8 G. Engineered Safety Features Response Time (Technical Specification 4.3.2.1.3) . .8 H. PORVs (Technical Specification 4.4.3.1.b) . .8

1. Low Temperature Overpressure System (Technical Specif. cation 4.4.9.3.1.b) . . .8 J. Remote Shutdown Panel Indication (Technical Specification Table 4.3-6).. .8

1. Reactor Coolant Cold Leg Temperature (Wide Range) (Table item 3).. .8

2. Pressurizer Pressure Ovide Range) (Table Item 4) . .9 )

3. Pressurizer Level (Table Item 5).. .9

4. Steam Generator Level (Wide Range) (Table item 6). .9

5. Steam Generator Pressure (Table item 7).. .9 K. PAM System (Technical Specification Table 4.3-10) . . .9 l

1. Containment Pressure (Table item 1).. .9

2. Reactor Coolant Outlet Temperature Ovide Range) (Table Item 3) . .9

3. Pressurizer Pressure (Wide Range) (Table item 4) . .9

4. Pressurizer Level (Wide Range) (Table item 5).. .9

5. Steam Generator Pressure (Table item 6).. .10

6. Steam Generator Level 6 Vide Range) (Table item 7). .10

7. AFW Flow Rate (Table Item 8). .10

8. RCS Subcooled Margin Monitor (Table item 9) . .10

9. PORV/ Safety Valve Acoustic Monitors (Table item 10). .10

10. Feedwater Flow (Table item 12). .10

11. Containment Water Level (Wide Range) (Table item 13) . .10 L. Containment Sump Level Alarm System (Technical Specification 4.4.6.1.b).. .10 2

ATTACilMENT 0)

INDEX SECTION PAGE #

M. Radiation Monitoring Instrumentation (Technical Specification Table 4.3-3.1) . .Ii

1. Containment Purge and Exhaust Isolation Radiation Monitoring System . . .I1 (Table Item 1.a)

2. Containment Area liigh Range Radiation Monitoring System (Table item 1.b).. .I1 REQUESTED CIIANGE. . .I1 SAFETY ANALYSIS . .I1 l A. GL 91-041ssues. .. . . . .12 B. Generic Safety Analysis Issues.. .13

]

1. Rosemount Transmitters.. .13

2. WEED Resistance Temperature Detectors. .13

3. Channel Functional Testing. . .13

4. Safe Plant Shutdown. . . .13

5. Instrument Performance Monitoring . . . . .14

6. Setpoints.. . . 14

7. Drift Analysis, Instrument Uncertainty and Setpoint Methodology. .14 l

8. Time Response Testing . . .15 l

9. Nuclear Instrument Calibration . .15

10. EfTect on Plant Safety . . . .15 C. RPS, ESFAS, PORVs and LTOP Instruments . .15

1. Generic RPS, ESFAS, PORVs and LTOP Instruments Discussion.. .16

2. RPS Wide Range Logarithmic Neutron Flux Monitor Trip (Table 4.3-1, item 11).. .I8

3. ESFAS (RWT Level- Low) RAS . . .I8

4. ESFAS (Containment Purge Valve Isolation) CRS . .I8

5. ESFAS (4.16 kV Bus Undervoltage) EDG Diesel Generator Start.. . .19

6. RPS Total Bypass Logic Functions . .19

7. RPS Time Response Testing . . .20

8. ESFAS Automatic Actuation Logic Circuitry. .20

9. ESFAS Total Bypass Logic Functions.. .20

10. ESFAS Time Response Testing.. .20

11. ESFAS Manual Trip Push Buttons and liandswitches . .20 D. Remote Shutdown Instrumentation.. .21 3

ATTACilMENT 0)

INDEX :

SECTION PAGE #

E PAM Instrumentation . . . .. 22

1. Primary PAM Instrument Functions Sections Evaluated . . . .22

2. Acoustic Valve Monitor . .23

3. Main Feedwater Flow.. .23 F. Radiation Monitoring Instrumentation.. . 23

1. Containment Purge and Exhaust Isolation Radiation Monitoring System . . . 23

2. Containment Area High Radiation Monitoring System. . 23

(

G. Containment Sump Level Alarm System. .24 H. Conclusion . . 24 DETERMINATION OF SIGNIFICANT HAZARDS.. .24 ENVIRONMENTAL ASSESSMENT. . .26 SCIIEDULE., . .27 SAFETY COMMITTEE REVIEW. . . .28 l

l 4

.. _ _ _ _ _ _ _ _ _ _ _ _ _ _

ML20084R017

Text

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