Text

Amends 142 & 121 to Licenses DPR-70 & DPR-75,respectively, Modifying RTS & ESFAS Instrument Sections & Associated Bases for Surveillance Test Intervals & AOT
	ML20056F022
Person / Time
Site:	Salem
Issue date:	08/04/1993
From:	Chris Miller; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20056F023	List: ML20056F022; ML20056F025;
References
	NUDOCS 9308250422
	Download: ML20056F022 (44)
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^

UNITED STATES

[

.j NUCLEAR REGULATORY COMMISSION

'f WASHINGTON, D.C. 205 5 0001

)

4,

,/

....+

PUBLIC SERVICE ELECTRIC & GAS COMPANY PHILADELPHIA ELECTRIC COMPANY DELMARVA POWER AND LIGHT COMPANY ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-272 SALEM NUCLEAR GENERATING STATION. UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.142 License No. DPR-70 1.

The Nuclear Regulatory Commission (the Commission or the NRC) has found that:

A.

The application for amendment filed by the Public Service Electric &

Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company (the licensees) dated May 11, 1992, and supplemented by letters dateo July 16, 1992, February 2, 1993, and July 2, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act),

and the Commission's rules and regulations set forth in 10 CFR Chapter I;

B.

The facility will operate in conformity with the application, the provisions of the Act, and. the rules and regulations of the Commission; C.

There is reasonable assurance: (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifica-tions as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-70 is hereby amended to read as follows:

9308250422 930804 PDR ADOCK 05000272 p

PDR

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 142, are hereby incorporated in the license.

The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of its date of issuance and shall be implemented within 120 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION l

harles L. Mi er, Director Project Directorate I-2 Division of Reactor Projects - I/II office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

August 4, 1993

(

l ATTACHMENT TO LICENSE AMENDMENT NO.142 FACILITY OPERATING LICENSE NO. DPR-70 DOCKET NO. 50-272 r

Revise Appendix A as follows:

Remove Paces Insert Paaes i

3/4 3-3 3/4 3-3 3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 3/4 3-6 3/4 3-6 3/4 3-7 3/4 3-7 3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-13 3/4 3-13

[

3/4 3-15 3/4 3-15 3/4 3-19 3/4 3-19 3/4 3-20 3/4 3-20 3/4 3-20a 3/4 3-20a 3/4 3-21 3/4 3-21 3/4 3-22 3/4 3-22 3/4 3-31a 3/4 3-31a 3/4 3-32 3/4 3-32 3/4 3-32a 3/4 3-32a 3/4 3-33 3/4 3-33 B 3/4 3-1 B 3/4 3-1

w k

TABLE 3.3-1 (Continuedi y

REACTOR TRIP SYSTEM INSTRUMENTATION E

Z MINIMUM TOTAL NUMBER CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 11.

Pressurizer Water Level--High 3

2 2

1,2 6#

l 12.

Loss of Flow - Single Loop 3/ loop 2/ loop in 2/ loop in 1

6#

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

13.

Loss of Flow - Two Loops 3/ loop 2/ loop in 2/ loop in 1

6#

(Above P-7 and below P-8) two oper-each oper-ating loops ating loop l

y 14.

Steam Generator Water Level--

3/ loop 2/ loop in 2/ loop in 1,2 6#

Low-Low any oper-each oper-ating loops ating loop l

15.

Steam /Feedwater Flow Mismatch 2/ loop-level 1/ loop-level 1/ loop-level 1,2 6#

and Low Steam Generator Water and 2/ loop-coincident and 2/ loop-Level flow mismatch with flow mismatch 1/ loop-flow or 2/ loop-mismatch in level and same loop 1/ loop-flow mismatch 26.

Undervoltage - Reactor 4-1/ bus 1/2 twice 3

1 6

Coolant Pumps 17.

Underfrequency - Reactor 4-1/ bus 1/2 twice 3

1 6

g Coolant Pumps E

i R-

-A E

~

.. ~

~_

TABLE 3.3-1 (Continued) g REACTOR TRIP SYSTEM INSTRUMENTATION 3

MINIMUM Z

TOTAL NUMBER CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 18.

Turbine Trip a.

Low Autostop Oil Pressure 3

2 2

1 6#

b.

Turbine Stop Valve Closure 4

4 3

1 6#

19.

Safety Injection Input from ESF 2

1 2

1,2 10 l

20.

Reactor Coolant Pump Breaker 1/ breaker 2

1/ breaker 1

11 Position Trip (above P-7) per opera-ting loop 21.

Reactor Trip Dreakers 2

1 2

1,2 1###, 14 u,

5 3*,4*,5*

13 Y

22.

Automatic Trip Logic 2

1 2

1,2 10 l

3*,4*,5*

13 x

k

.E 44

. - ~.

, ~_-

l i

i I

TABLE 3.3-1 (Continued) l TABLE NOTATION l

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

The provisions of Specification 3.0.4 are not applicable.

High voltage to detector may be de-energized above P-6.

1

1. 1. If ACTION Statement 1 is entered as a result of Reactor Trip Breaker (RTB) or Reactor Trip Bypass Breakers (RTBB) maintenance testing results exceeding the following acceptance criteria, NRC reporting shall be made within 30 days in accordance with Specification 6.9.2 1.

A RTB or RTBB trip failure during any surveillance test with less than or equal to 300 grams of weight added to the breaker trip bar.

2.

A RTB or RTBB time response failure that results in the overall reactor trip system time response exceeding the Technical Specification limit.

ACTION STATEMENTS ACTION 1 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, be in HOT STANDBY within 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 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per specification 4.3.1.1.1 l

provided the other channel is OPERABLE.

\\

ACTION 2 -

With the number of OPERABLE channels one less than the Total l

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 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

c.

Either, THERMAL POWER is restricted to s 75% of RATED THERMAL POWER and the Power Range, Neutron Flux trip setpoint is reduced to s 85% of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

c t

i l

SALEM - UNIT 1 3/4 3-5 Amendment No.142 e

l l

TABLE 3.3-1 (Continued 1 ACTION 3 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a.

Below P-6, restore the inoperable channel to OPERABLE l

status prior to increasing THERMAL POWER above the P-6 Setpoint.

I b.

Above P-6 but below 5% of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to l

increasing THERMAL POWER above 5% of RATED THERMAL

{

POWER.

c.

Above 5% of RATED THERMAL POWER, POWER OPERATION may t

continue.

ACTION 4 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a.

Below P-6, restore the inoperable channel to OPERABLE I

status prior to increasing THERMAL PCWER above the P-6 l

Setpoint.

l b.

Above P-6, operation may continue.

i ACTION 5-With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, verif:r compliance with the SHUTDOWN MARGIN requirements of Specification 3.1.1.1 or 3.1.1.2, as applicable, within I hour and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

ACTION 6 -

With the number of OPERABLE channels one less than the f

Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

i The inoperable channel is placed in the tripped a.

condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

I b.

The Minimum Channels OPERABLE requirement is met; l

however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

ACTION 7 -

NOT USED i

ACTION 8 -

NOT USED ACTION 9 -

NOT USED l

i i

SALEM - UNIT 1 3/4 3-6 Amendment No.142 i

I

l TABLE 3.3-1 (Continued)

ACTION 10 -

With the number of OPERABLE Channels one leos than f

the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT STANDBY in the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up l

to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.1.1.1 provided the other channel is OPERABLE.

ACTION 11 -

With less than the Minimum Number of Channels OPERABLE, operation may continue provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l ACTION 12 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 13 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour.

l ACTION 14 -

With one of the diverse trip features (Undervoltage or shunt trip attachment) inoperable, restore it to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . The breaker shall not be bypassed while one of the diverse trip features is inoperable except for the time required for performing j

maintenance to restore the breaker to OPERABLE status.

REACTOR TRIP SYSTEM INTERLOCKS I

i DESIGNATION CONDITION AND SETPOINT FUNCTION i

P-6 With 2 of 2 Intermediate Ranog P-6 prevents or defeats Neutron Flux Channels < 6x10 the manual block of amps.

source range reactor trip.

P-7 With 2 of 4 Power Range Neutror P-7 prevents or defeats Flux Channels 2 11% of RATED the automatic block of THERMAL POWER or 1 of 2 Turbine reactor trip on: Low impulse chamber pressure channels flow in more than one 2 a pressure equivalent to 11% of primary coolant loop, RATED THERMAL POWER.

reactor coolant pump undervoltage and under-f requency, pressurizer low pressure, pressurizer high level,'and the opening of more than one reactor coolant I

pump breaker.

SALEM - UNIT 1 3/4 3-7 Amendment No.142 l

6 h

TABLE 4.3-1 9

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS E

U CHANNEL HODES IN WilICH

~

CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CliECK CALIBRATION TEST REOUIRED 1.

Manual Reactor Trip Switch N.A.

N.A.

S/U(9)

N.A.

2.

Power Range, Neutron Flux 5

D(2), M(3)

Q 1,2 l

and Q(6) 3.

Power Range, Neutron Flux, N.A.

R(6)

Q 1,2 l

High Positive Rate 4.

Power Range, Neutron Flux, N.A.

R(6)

Q 1,2 l

liigh Negative Rate w

n

[

5.

Intermediate Range, Neutron S

R(6)

S/U(1) 1,2 and

Flux 6.

Source Range, Neutron Flux S(7)

R(6)

Q and S/U(1) 2,3,4,5 and

l L

7.

Overtemperatura AT S

R Q

1,2 8.

Overpower AT S

R Q

1,2 l

9.

Pressurizer Pressure--Low S

R Q

1,2 l

8 l

=

g 10.

Pressurizer Pressure--liigh S

R Q

1,2 A

=

11.

Pressurizer Water Level--High S R

Q 1,2 12.

Loss of Flow - Single Loop S

R Q

1 l

N

~..

k g

TABLE 4.3-I (Continued)

E f

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS E

Q CHANNEL MODES IN WHICH CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 13.

Loss of Flow - Two Loops S

R N.A.

1 14.

Steam Generator Water Level--

S R

Q 1,2 h

Low-Low

'15.

Steam /Feedwater Flow Mismatch &

S R

Q 1,2 l

Low Steam Generator Water Level

16. Undervoltage - Reactor Coolant N.A.

R Q

1 l

y Pumps a

17. Underfrequency - Reactor Coolant N.A.

R Q

1 N

Pumps

18. Turbine Trip A.

Low Autostop Oil Pressure N.A.

N.A.

S/U(1) 1,2 B.

Turbine Stop Valve Closure N.A.

N.A.

S/U(1) 1,2

19. Safety Injection Input from ESF N.A.

N.A.

M(4)(5) 1,2

20. Reactor Coolant Pump Breaker N.A.

N.A.

R N.A.

k Position Trip El

21. Reactor Trip Breaker N.A.

N.A.

S/U(10),

1,2 and *

[

M(11,13),

P SA(12,13) 7, and R(14)

N

22. Automatic Trip Logic N.A.

N.A.

M(5) 1,2 and *

,m TABLE 4.3-1 (Continued)

NOTATION I

With the reactor trip system breakers closed and the control rod drive system capable of rod withdrawal.

(1)

If not performed in previous 31 days.

l (2)

Heat balance only, above 15% of RATED THERMAL POWER.

(3)

Compare incore to excore axial offset above 15% of RATED THERMAL i

POWER. Recalibrate if absolute difference 2 3 percent.

(4)

Manual SSPS functional input check every 18 months.

l (5)

Each train or logic channel shall be tested at least every 62 days on a STAGGERED TEST BASIS.

l (6)

Neutron detectors may be excluded from CHANNEL CALIBRATION.

Below P-6 (Block of Source Range Reactor Trip) setpoint.

(7)

(B)

Deleted (9)

If not performed in the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , conduct a functional test of the Manual Reactor Trip Switches to verify the Manual Reactor Trip Switch and the independent operation of the U.V. and shunt trip wiring.

(10) -

If not performed in the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , conduct a functional test of:

Reactor Trip Breaker independent operation of U.V. and Shunt Trip (via SSPS)

Reactor Trip Breaker Shunt Trip (via manual pushbutton controls) i (11) -

Perform a functional test of:

Reactor Trip Breaker independent operation of U.V. Trip and Shunt Trip (via SSPS) and conduct response time testing of U.V.

and Shunt l

Trip / Breakers (event recorders)

Reactor Trip Breaker Shunt Trip (via manual pushbutton controls)

(12) -

Perform periodic maintenance on Reactor Trip Breakers and Reactor f

Trip Bypass Breakers semiannually as follows:

i a.

response time testing, (3 times) (visicorder) trend data b.

trip bar lift force measurements c.

UV output force measurement d.

dropout voltage check e.

servicing / lubrication / adjustments (See Table 3.3-1 Notation

1. 1. )

f.

repeat testing steps (a-d) following any necessary actions at step (e)

SALEM - UNIT 1 3/4 3-13 Amendment No.142 e

a y,

TABLE 3.3-3 N

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION h

MINIMUM

[

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 1.

SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION a.

Manual Initiation 2

1 2

1,2,3,4 18 b.

Automatic Actuation Logic 2

1 2

1,2,3,4 13 c.

Containment Pressure-High 3

2 2

1,2,3 19a l

l d.

Pressurizer Pressure-Low 3

2 2

1,2,3#

19*

e.

Differential Pressure Between 3/ steam line 2/ steam line 2/ steam 1,2,3##

19*

l Steam Lines - High any steam line w

A line Y

U f.

Steam Flow in Two Steam 2/ steam line 1/ steam line 1/ steam 1,2,3##

19*

l Lines-High any 2 steam line lines COINCIDENT WITH EITHER l

Tavg--Low-Low 1 Tavg/ loop 1 Tavg in 1 Tavg 1,2,3##

19*

any 2 loops in any 3 loops OR, COINCIDENT WITH f

Steam Line Pressure-Low 1 pressure /

1 pressure 1 pressure 1,2,3##

19*

l E

loop any 2 loops any 3 loops a

.E

~

g TABLE 3.3-3 (Continued) 5 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION h

MINIMUM

[

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CllANNELS TO TRIP OPERABLE MODES ACTION 4.

STEAM LINE ISOLATION a.

Manual 2/ steam line 1/ steam line 1/ operating 1,2,3 23 steam line b.

Automatic Actuation Logic 2***

1 2

1,2,3 20 c.

Containment Pressure--liigh-High 4

2 3

1,2,3 16 d.

Steam Flow in Two steam 2/ steam line 1/ steam line 1/ steam line 1,2 3##

19*

t' Lines--High any 2 steam lines COINCIDENT WITH EITHER f

Tavg--Low-Low 1 Tavg/ loop 1 Tavg in 1 Tavg in 1,2,3##

19*

any 2 loops any 3 loops OR, COINCIDENT WITH Steam Line Pressure-Low I pressure /

1 pressure 1 pressure 1,2,3##

19*

loop any 2 loops any 3 loops k

k E

~

m

TABLE 3.3-3 (Continued) g?

5!

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION k

MINIMUM

']

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 5.

TURBINE TRIP & FEEDWATER ISOLATION

-l a.

Steam Generator Water level--

3/ loop 2/ loop in 2/ loop in 1,2,3 19*

High-High any operating each operating loop loop 6.

SAFEGUARDS EQUIPMENT 3

2 3

1,2,3,4 13 CONTROL SYSTEM (SEC) 7.

UNDERVOLTAGE, VITAL BUS M

^

a.

Loss of Voltage 1/ bus 2

3 1,2,3 14*

4 b.

Sustained Degraded Voltage 3/ bus 2/ bus 3/ bus 1,2,3 14*

k k

E.

~

TABLE 3.3-3 fcontinued) g E

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION k

MINIMUM

[

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 8.

AUXILIARY FEEDWATER a.

Automatic Actuation Logic **

2 1

2 1,2,3 20 b.

Manual Initiation 1/ pump 1/ pump 1/ pump 1,2,3 22 c.

Steam Generator Water Level--Low-Low l

i.

Start Motor Driven Pumps 3/stm. gen.

2/stm. gen.

1,2,3 19*

y any stm. gen.

a.

[

ii.

Start Turbine Driven Pumps 3/stm. gen.

2/stm. gen.

1,2,3 19*

l

!?

any 2 stm.

gen.

d.

Undervoltage - RCP Start 4-1/ bus 1/2 x 2 3

1,2 19 Turbine - Driven Pump e.

S.I.

Start Motor-Driven Pumps See 1 above (All S.I.

Initiating functions and requirements) f.

Trip of Main Feedwater Pumps 2/ pump 1/ pump 1/ pump 1,2 21*

Start. Motor Driven Pumps 9

Station Blackout See 6 and 7 above (SEC and U/V Vital Bus) 7 R

a S

N

. -. ~.

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

i I

f TABLE 3.3-3 (Continued) f TABLE NOTATION Trip function may be bypassed in this MODE below P-11.

I Trip function may be bypassed in this MODE below P-12.

I The provisions of Specification 3.0.4 are not applicable.

Applies to Functional Unit 8 items c and d.

l The automatic actuation logic includes two redundant solenoid operated vent valves for each Main Steam IS0lation Valve.

One vent valve on any one Main Steam Isolation valve may be isolated without affecting i

the function of the automatic actuation logic provided the remaining i

seven solenoid vent valves remain OPERABLE. The isolated MSIV vent l

valve shall be returned to OPERABLE status upon the first entry into MODE 5 following determination that the vent valve is inoperable.

For any condition where more than one of the eight solenoid vent valves are inoperable, entry into ACTION 20 is required.

ACTION STATEMENTS ACTION 13 -

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

Number of Channels, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or, be in HOT STANDBY within i

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 ; however, one channel may be bypassed for up to 4 i

hours for surveillance testing per Specification 4.3.2.1.1 provided the other channel is OPERABLE.

i ACTION 14 -

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed until performance l

of the next required CHANNEL FUNCTIONAL TEST, provided the l

inoperable channel is placed in the tripped condition within 1 l

hour.

ACTION 15 -

NOT USED ACTION 16 -

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 by CHANNEL CHECK within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; one additional channel may be 1

bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per

[

Specification 4.3.2.1.1.

ACTION 17 -

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

ACTION 18 -

With the number of OPERABLE Channals 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 .

SALEM - UNIT 1 3/4 3-21 Amendment No.142

TABLE 3.3-3 (Continued)

ACTION 19 -

With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may i

proceed provided the following conditions are satisfied:

The inoperable channel is placed in the tripped a.

condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l The Minimum Channels OPERABLE requirements is mets b.

however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

ACTION 20 -

With the number of OPERABLE channels one less than the Total i

Number of Channels, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 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 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 to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1 provided the other channel is OPERABLE.

l ACTION 21 -

With the number of OPERABLE channels one less than the Minimum Number of Channels, operation may proceed provided l

that either:

-i a.

The inoperable channel is restored to OPERABLE within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or b.

If the affected Main Feedwater Pump is expected to be

[

out of service for more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the inoperable

(

channel is jumpered so ts to enable the Start Circuit i

of the Auxiliary Feedwater Pumps upon the loss of the other Main Feedwater Pump.

ACTION 22 -

With the number of OPERABLE channels relating directly with the number of OPERABLE auxiliary feedwater pumps, the-ACTIONS of L.C.O.

3.7.1.2 apply.

ACTION 23 -

With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to l

OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within.

)

the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the l

following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

i

-i e

t i

SALEM - UNIT 1 3/4 3-22 Amendment No.142 l

e y,

TABLE 4.3-2 7

ENGIt<EERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION e

SURVEILLANCE REQUIREMENTS 5

-4 CHANNEL MODES IN WHICH w

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUERED 1.

SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION

a. Manual Initiation N.A.

N.A.

R 1,2,3,4

b. Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4

c. Containment Pressure-High S

R Q(3) 1,2,3 l

d. Pressurizer Pressure--Low S

R Q

1,2,3 l

{

e.

Differential Pressure Between S

R Q

1,2,3 Steam Lines--High

~

f. Steam Flow in Two Steam S

R Q

1,2,3 l

Lines--High coincident with Tavg--Low-Low or Steam Line Pressure-Low 2.

CONTAINMENT SPRAY a.

Manual Initiation N.A.

N.A.

R 1,2,3,4

b. Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4 i

g

c. Containment Pressure--High-High S

R Q(3) 1,2,3 l

o.

E

.E N

. ~...........

... ~.

. ~.

i TABLE 4.3-2 (Continued) wN S

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION h

SURVEILLANCE REOUIREMENTS 5

[

CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALI B RATION TEST REOUIRED 3.

CONTAINMENT ISOLATION a.

Phase "A"

Isolation 1.

Manual N.A.

N.A.

R 1,2,3,4 2.

From Safety Injection N.A.

N.A.

M(2) 1,2,3,4 Automatic Actuation Logic

{

b.

Phase "B"

Isolation 1.

Manual N.A.

N.A.

R 1,2,3,4 2.

Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4 3.

Containment Pressure--

S R

Q(3) 1,2,3 l

High-High

c. Containment Ventilation Isolation 1.

Manual N.A.

N.A.

R 1,2,3,4 2.

Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4 3

8 h

3.

Containment Atmosphere Gaseous Per table 4.3-3 Radioactivity - High 5

tQ m

y TABLE 4.3-2 (Continued)

E f

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION g

SURVEILLANCE REOUIREMENIS Z

CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 4.

STEAM LINE ISOLATION a.

Manual N.A.

N.A.

R 1,2,3 b.

Automatic. Actuation Logic N.A.

N.A.

M(2) 1,2,3 c.

Containment Pressure--

S R

Q(3) 1,2,3 l

High-High d.

Steam Flow in Two Steam S

R Q

1,2,3 l

y Lines--High Coincident with ks Tavg--Low-Low or Steam Line Pressure--Low 5.

TURBINE TRIP AND FEEDWATER ISOLATION a.

Steam Generator Water S

R Q

1,2,3 Level--High-High 6.

SAFEGUARDS EQUIPMENT CONTROL SYSTEM (SEC) LOGIC a.

Inputs N.A.

N.A.

M(6) 1,2,3,4 b.

Logic, Timing and Outputs N.A.

N.A.

M(1) 1,2,3,4 5

k 3

7.

UNDERVOLTAGE, VITAL BUS a.

Loss of Voltage S

R M

1,2,3 5

N b.

Sustained Degraded Voltage S

R M

1,2,3

9 TABLE 4.3-2 (Continued) m?

E ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS

[

CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REObfRED 8.

AUXILIARY FEEDWATER a.

Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3 b.

Manual Initiation N.A.

N.A.

M(5) 1,2,3 c.

Steam Generator Water S

R Q

1,2,3 l

Level--Low-Low d.

Undervoltage - RCP S

.R Q

1,2 l

Y O

e.

S.I.

See 1 above (All S.I.

surveillance requirements) f.

Trip of Main Feedwater Pumps N.A.

N.A.

R 1

g.

Station Blackout See 6b and 7 above (SEC and U/V Vital Bus) k k

6 w

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

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

.__.u.-_--_-.__._._,_..~'

I i

l l

3/4.3 INSTRUMENTATION l

r f*

BASES 3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP)

INSTRUMENTATION i

The OPERABILITY of the protective and ESF instrumentation systems and.

interlocks ensure that 1) the associated ESF action and/or reactor trip will l

be initiated when the parameter monitored by each channel or combination l

thereof exceeds its setpoint, 2) the specified coincidence logic and sufficient redundancy is maintained to permit a channel to be out of service for testing j

or maintenance consistent with maintaining an appropriate level of reliability I

f of the Reactor Protection and Engineered Safety Features instrumentation and, 3) i sufficient system functions capability is available from diverse parameters.

The OPERABILITY of these systems is required to provide the overall i

reliability, redundance and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses.

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

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP-10271, " Evaluation of Surveillance i

Frequencies and Out of Service Times for the Reactor Protection i

Instrumentation System," and Supplements to that report.

Surveillance intervals and out of service times were determined based on maintaining an appropriate level of reliability of the Reactor Protection System and i

Engineered Safety Features instrumentation.

The measurement of response time at the specified frequencies provides assurance that the protective and ESF action function associated with each channel is completed within the time limit assumed in the accident analyses.

No credit was taken in the analyses for those channels with response times indicated as not applicable.

Response time may be demonstrated by any series of sequential, overlapping or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test measurements or 2) utilizing replacement sensors with certified response times.

1 3/4.3.3 MONITORING INSTRUMENTATION 3/4.3.3.I RADIATION MONITORING INSTRUMENTATION The OPERABILITY of the radiation monitoring channels ensures that

1) the radiation levels are continually measured in the areas served 1

SALEM - UNIT 1 B 3/4 3-1 Amendment NO.142

i y CECy f.

UNITED STATES

~

t El.0*

E NUCLEAR REGULATORY COMMISSION 1h' WASHINGTON, D.C. 20556-0301 s...../

PUBLIC SERVICE ELECTRIC & GAS COMPANY PHILADELPHIA ELECTRIC COMP 6NJ DELMARVA POWER AND LIGHT COMPANY ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-311 SALEM NUCLEAR GENERATING STATION. UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.121 License No. OPR-75 1.

The Nuclear Regulatory Comission (the Comission or the NRC) has found that:

A.

The application for amendment filed by the Public Service Electric &-

Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company (the licensees) dated May 11, 1992, and supplemented by letters dated July 16, 1992, February 2, 1993, and July 2, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act),

and the Comission's rules and regulations set forth in 10 CFR Chapter I;

B.

The facility will operate in conformity with the appl u 4 ion, the provisions of the Act, and the rules and regulations of the Comission; C.

There is reasonable assurance: (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Comission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifica-tions as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-75 is hereby amended to read as follows:

(2) Technical Soecifications and Environmental Protection Plan The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 121, are hereby incorporated in the license.

The licensee shall operate the facility in accordance with i

the Technical Specifications.

3.

This license amendment is effective as of its date of issuance and shall be implemented within 120 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION i.

sL-

,e harles L. M er, Director Project Directorate I-2 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance: August 4, 1993 b

h 1

i i

ATTACHMENT TO LICENSE AMENDMENT NO.121 l

r FACILITY OPERATING LICENSE NO. OPR-75 i

DOCKET NO. 50-311 l

Revise Appendix A as follows:

~

Remove Paaes Insert Paaes 3/4 3-3 3/4 3-3 3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 3/4 3-6 3/4 3-6 i

3/4 3-7 3/4 3-7 f

3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 I

3/4 3-13 3/4 3-13 3/4 3-15 3/4 3-15 3/4 3 3/4 3-19 3/4 3-20 3/4 3-20 3/4 3-21 3/4 3-21 3/4 3-22 3/4 3-22 3/4 3-23 3/4 3-23 i

3/4 3-33 3/4 3-33 f

3/4 3-34 3/4 3-34 3/4 3-35 3/4 3-35 3/4 3-36 3/4 3-36 B 3/4 3-1 B 3/4 3-1 i

?

I

y TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION Eq MINIMUM m

TOTAL NUMBER CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNEL 5 TO TRIP OPE RABL_F, MODES ACTION 11.

Pressurizer Water Level 3

2 2

1,2 6#

--High 12.

Loss of Flow - Single Loop 3/ loop 2/ loop in 2/ loop in 1

6#

l (Above P-8) any oper-each oper-ating loop ating loop 13.

Loss of Flow - Two Loops 3/ loop 2/ loop in 2/ loop in 1

6#

l (Above P-7 and below P-8) two oper-each oper-ating loops ating loop M{

14.

Steam Generator Water 3/ loop 2/ loop in 2/ loop in 1,2 6#

l 4,

Level--Low-Low any oper-each oper-ating loops ating loop 15.

Steam /Feedwater Flow 2/ loop-level 1/ loop-level 1/ loop-level 1,2 6#

l Mismatch and Low steam and coincident and Generator Water Level 2/ loop-flow with 2/ loop-flow mismatch 1/ loop-flow mismatch or mismatch in 2/ loop-level same loop and 1/ loop-flow mismatch y

16.

Undervoltage-Reactor 4-1/ bus 1/2 twic=

3 1

6

{

coolant Pumps 8

5 17.

Underfrequency-Reactor 4-1/ bus 1/2 twice 3

1 6

y Coolant Pumps w

g TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION c

MINIMUM h

TOTAL NUMBER CIIANNELS CilANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION m

18. Turbine Trip a.

Low Autostop Oil Pressure 3

2 2

1 6#

b.

Turbine Stop Valve Closure 4

4 3

1 6#

19. Safety Injection Input from ESF 2

1 2

1,2 10 l

20. Reactor Coolant Pump Breaker 1/ breaker 2

1/ breaker 1

11 Position Trip (above P-7) per opera-ting loop

21. Reactor Trip Breakers 2

1 2

1,2 1###, 14 Y

3*,4*,5*

13

=

22. Automatic Trip Logic 2

1 2

1,2 10 l

3*,4*,5*

13 E

a ar

.O

.. ~

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

TABLE 3.3-1 (continued)

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

The provisions of Specification 3.0.4 are not applicable.

High voltage to detector may be de-energized above P-6.

1. 1. If ACTION Statenent 1 is entered as a result of Reactor Trip Breaker.

(RTB) or Reactor Trip Bypass Breaker (RTBB) maintenance testing results exceeding the following acceptance criteria, NRC reporting shall be made within 30 days in accordance with Specification 6.9.2 1.

A RTB or RTBB trip failure during any surveillance test with less than or equal to 300 grams of weight added to the breaker trip bar.

2.

A RTB or RTBB time response failure that results in the overall reactor trip system time response exceeding the Technical Specification limit.

ACTION STATEMENTS l

t ACTION 1 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, be in HOT STANDBY within 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 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1.1 provided the other channel is OPERABLE.

l ACTION 2 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may j

proceed provided the following conditions are satisfied 1

The inoperable channel is placed in the tripped condition a.

within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l t

b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

c.

Either, THERMAL POWER is restricted to s 75% of RATED THERMAL POWER and the Power Range, Neutron Flux trip setpoint is reduced to 6 85% of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, j

the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

y d.

The QUADRANT POWER TILT RATIO, as indicated by the remaining three detectors, is verified consistent with the normalized symmetric power distribution obtained by using the movable in-core detectors in the four pairs of symmetric

^

thimble locations at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months when THERMAL i

POWER is greater than 75% of RATED THERMAL POWER.

SALEM - UNIT 2 3/4 3-5 Amendment No.121 r

h t

TABLE 3,3-1 (Continued)

ACTION 3 -

With the number of channels OPERABLE one less than required i

by the. Minimum Channels OPERABLE requirement and with the'

)

THERMAL POWER level:

l a.

Below P-6, restore the inoperable channel to OPERABLE.

status prior to increasing THERMAL POWER above the P-6 i

Setpoint.

5 b.

Above P-6, but below 5% of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 5% of RATED-THERMAL POWER.

l c.

Above 5% of RATED THERMAL POWER, POWER OPERATION may continue.

d.

Above 10% of RATED THERMAL' POWER, the provisions of Specification 3.0.3 are not applicable.

ACTION 4 -

With the number of channels OPERABLE one less than required?

by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level i

a.

Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 Setpoint.

b.

Above P-6, operation may continue.

+

ACTION 5 -

With the number of channels OPERABLE one less-than required by the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN requirements of Specification 3.1.1.1 or 3.1.1.2, as applicable, within i

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

ACTION 6 -

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:

The inoperable channel is placed in the trippee.

a.

condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

The Minimum channel OPERABLE requirement is met; j

however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

l ACTION 7 -

NOT USED ACTION 8 -

NOT USED i

ACTION 9 -

NOT USED f

SALEM - UNIT 2 3/4 3-6 Amendment No.121

TABLE 3.3-1 (Continued)

~

ACTION 10 -

With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status.within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT STANDBY in the next 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 i

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.1.1.1 provided the other channel is OPERABLE.

f l

ACTION 11 -

With less than the Minimum Number of Channels OPERABLE, operation may continue provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l ACTION 12 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 13 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour.

ACTION 14 -

With one of the diverse trip features (Undervoltage or shunt trip attachment) inoperable, restore it to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . The breaker shall not be bypassed while one of the' diverse trip features is inoperable except for the time required for performing maintenance to i

restore the breaker to OPERABLE status.

REACTOP TRIP SYSTEM INTERLOCKS DESIGNATION CONDITION AND SETPOINT FUNCTION P-6 With 2 of 2 Intermediate Rangg

-P-6 prevents or defeats Neutron Flux Channels < 6x10 the manual block of amps.

source range reactor trip.

P-7 With 2 of 4 Power Range Neutron P-7 prevents or defeats Flux channels 2 11% of RATED the automatic block of THERMAL POWER or 1 of 2 Turbine reactor trip on: Low impulse chamber pressure flow in more than one i

channels 2 a pressure equivalent primary coolant loop,-

to 11% of RATED THERMAL POWER.

reactor coolant pump undervoltage and under-f requ ency, pressurizer low pressure, pressurizer high level, and the opening of more than i

one reactor coolant l

pump breaker.

f SALEM - UNIT 2 3/4 3-7 Amendment No.121 I

e v,

TABLE 4.3-1 N

l'EACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WilICH CHANNEL FUNCTIONAL SURVEILLANCE y

FUNCTIONAL UNIT CIIECK CALIBRATION TEST REOUIRED 1.

Manual Reactor Trip Switch N.A.

N.A.

S/U(9)

N.A.

2.

Power Range, Neutron Flux S

D(2), M(3)

Q 1,2 l

and Q(6) 3.

Power Range, Neutron Flux, N.A.

R(6)

Q 1,2 l

High Positive Rate 4.

Power Range, Neutron Flux, N.A.

R(6)

Q 1,2 l

g High Negative Rate Y

Z 5.

Intermediate Range, Neutron Flux S

R(6)

S/U(1) 1,2 and

l 6.

Source Range, Neutron Flux S(7)

R(6)

Q and S/U(1) 2,3,4,5 and

7.

Overtemperature AT S

R Q

1,2 l

8.

Overpower AT S

R Q

1,2 l

9.

Pressurizer Pressure--Low S

R Q

1,2 l

10.

Pressurizer Pressure--High S

R Q

1,2 l

'k 11.

Pressurizer Water Level--High S

R Q

1,2 Ee 3

12.

Loss of Flow - Single Loop S

R Q

1 l

c+

0

~

t

..,n-v

.. n v.

~

-~<s

.,-,-.--e-aw n..

n.,r-,

-.,.-.,,-en-.

4 TABLE 4.3-1 (Continued)

E REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS C$

CHANNEL MODES IN WHICH-

[

CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED

13. Loss of Flow - Two Loops S

R N.A.

1

14. Steam Generator Water Level--

S R

Q 1,2 l

Low-Low

15. Steam /Feedwater Flow Mismatch &

S R

Q 1,2 l

Low Steam Generator Water Level

'16. Undervoltage - Reactor Coolant N.A.

R Q

1 u,

1 Pumps l

17. Underfrequeacy - Reactor Coolant N.A.

R Q

1 Pumps

18. Turbine Trip a.

Low Autostop Oil Pressure N.A.

N.A.

S/U(1)

N.A.

b. Turbine Stop Valve Closure N.A.

N.A.

S/U(1)

N.A.

19. Safety Injection Input from ESF N.A.

N.A.

M(4)(5) 1,2

20. Reactor Coolant Pump Breaker N.A.

N.A.

R N.A.

g Position Trip k

21. Re-ctor Trip Breaker N.A.

N.A.

S/U(10),

1,2 and

5 M(11,13),

g SA(12,13) and R(14) i

~d

22. Automatic Trip Logic N.A.

N.A.

M(5)'

1,2 and *

. ~.

_~

-=

1 TABLE 4.3-1-(Continued)

NO*ATION With the reactor trip system breakers closed and the control rod drive system capable of rod withdrawal.

(1)

If not performed in previous 31 days.

l 4

I l

(2) -

Heat balance only, above 15% of RATED THERMAL POWER.

i (3)

Compare incere to excore axial offset above 15% of RATED THERMAL f

POWER. Recalibrate if absolute difference 2 3 percent.

I (4) -

Manual SSPS functional input check every 18 months.

(5)

Each train or logic channel shall be tested at least every 62 days on a STAGGERED TEST BASIS.

(6) -

Neutron detectors may be excluded from CHANNEL CALIBRATION.

I (7) -

Below P-6 (Block of Source Range Reactor Trip) setpoint.

(8)

Deleted I

(9) -

If not performed in the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , conduct a functional test of the Manual Reactor Trip Switches to verify the Manual Reactor Trip Switch and the independent operation of the U.V.

and shunt trip wiring.

1 (10) -

If not performed in the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , conduct a functional test of:

Reactor Trip Breaker independent operation of U.V.

and Shunt Trip (via SSPS)

Reactor Trip Breaker Shunt Trip (via manual pushbutton controls)

(11) -

Perform a functional test of:

Reactor Trip Ereaker independent operation of U.V. Trip and Shunt Trip (via SSPS) and conduct response time testing of U.V.

I and Shunt Trip / Breakers (event recorders)

Reactor Trip Breaker Shunt Trip (via manual push'ntton controls)

(12) -

Perform periodic maintenance on Reactor Trip Breakers and Reactor l

Trip Bypass Breakers semiannually as follows:

a.

response time testing, (3 times) (visicorder) trend data b.

trip bar lift force measurements c.

U.V.

output force measuremer.t d.

dropout voltage check i

SALEM - UNIT 2 3/4 3-13 Amendment No.121 l

TABLE 3.3-3 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM Z

TOTAL NO.

CHANNELS CHANNELS APPLICABLE N

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE

__ MODES ACTION 1.

SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION a.

Manual Initiation 2

1 2

1,2,3,4 18 b.

Automatic Actuation Logic 2

1 2

1,2,3,4 13 Containment Pressure-High 3

2 2

1,2,3 19*

l c.

d.

Pressurizer Pressure-Low 3

2 2

1,2,3#

19*

l l

e.

Differential Prer7ure Batween 3/ steam line 2/ steam line 2/ steam 1,2,3##

19*

u, 1

Steam Lines - High any steam line y

line G

l f.

Steam Flow in Two 2/ steam line 1/ steam line 1/ steam 1,2,3##

19*

Steam Lines-High any 2 steam line lines COINCIDENT WITH EITHER l

Tavg--Low-Low 1 Tavg/ loop 1 Tavg in 1 Tavg 1,2,3##

19*

any 2 loops in any 3 loops OR, COINCIDENT WITH y

Steam Line Pressure-Low 1 pressure /

1 pressure 1 pressure 1,2,3##

19*

l

g loop any 2 loops any 3 loops a

.F

TABLE 3.3-3 (Continued)

E ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM I4 TOTAL No.

CHANNELS CHANNELS APPLICABLE N

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 4.

STEAM LINE ISOLATION a.

Manual 2/ steam line 1/ steam line 1/ operating 1,2,3 23 steam line b.

Automatic Actuation Logic 2***

1 2

1,2,3 20 c.

Containment Pressure--

4 2

3 1,2,3 16 High-High d.

Steam Flow in Two 2/ steam line 1/ steam line 1/ steam line 1,2,3f#

19*

l 2

Steam Lines--High any 2 steam y

lines COINCIDENT WITH EITHER T

--Low-Low 1T

/ loop 1T in 1T in 1,2,3##

19*

l

- 9

- 9 any 391 oops any 391 oops OR, COINCIDENT WITH l

Steam Line Pressure-Low 1 pressure /

1 pressure 1 pressure 1,2,3##

19*

loop any 2 loops any 3 loops

$a 3

E

&L

e TABLE 3.3-3 (Continued)

?

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION C5 MINIMUM

[

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 5.

TURDINE TRIP & FEEDWATER ISOLATION a.

Steam Generator Water 3/ loop 2/ loop in 2/ loop in 1,2,3 19*

1evel--High-High any operating each operating loop loop 6.

SAFEGUARDS EQUIPMENT CONTROL 3

2 3

1,2,3,4 13 SYSTEM (SEC) 7.

UNDERVOLTAGE, VITAL BUS a.

Loss of Voltage 1/ bus 2

3 1,2,3 14*

y b.

Sustained Degraded Voltage 3/ bus 2/ bus 3/ bus 1,2,3 14*

E N

R E

.E

.. ~ -. -.

~ -..

TABLE 3.3-3 (Continued) h ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION e

MINIMUM g

TOTAL NO.

CllANNELS CliANNELS APPLICABLE Q

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION N

8.

AUXILIARY FEEDWATER a.

Automatic Actuation Logic **

2 1

2 1,2,3 20 b.

Manual Initiation 1/ pump 1/ pump 1/ pump 1,2,3 22 c.

Stm. Gen. Water Level-Low-Low 1.

Start Motor Driven Pumps 3/stm. gen.

2/stm. gen.

1,2,3 19*

l any stm. gen.

l 11.

Start Turbine Driven Pumps 3/stm. gen.

2/stm. gen.

1,2,3 19*

w D

any 2 stm.

y gen.

d.

Undervoltage - RCP Start 4-1/ bus 1/2 x 2 3

1,2 19 Turbine - Driven Pump e.

S.I.

Start Motor-Driven Pumps See 1 above (All S.I.

initiating functions and requirements) f.

Trip of Main Feedwater Pumps 2/ pump 1/ pump 1/ pump 1,2 21*

Start Motor-Driven Pumps g.

Station Blackout See 6 and 7 above (SEC and UV Vital Bus) 9.

SEMIAUTOMATIC TRANSFER TO RECIRCULATION k

a.

RWST Level Low-4 2

3 1,2,3 16 h

f b.

Automatic Actuation Logic 2

1 2

1,2,3 20 g

N

~

..s.

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

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

i TABLE 3.3-3 (Continued)

~

TABLE NOTATION Trip function may be bypassed in this MODE below P-11.

Trip function may be bypassed in this MODE below P-12.

The provisions of Specification 3.O.4 are not applicable.

Applies to Functional Unit 8 items e and d.

The automatic actuation logic includes two redundant solenoid operated vent valves for each Main Steam Isolation Valve. One vent valve on any one Main Steam Isolation valve may be isolated without affecting the function of the automatic actuation logic provided the remaining seven solenoid vent valves remain OPERABLE.

The isolated MSIV vent

\\.

valve shall be returned to OPERABLE status upon the first entry into MODE 5 following determination that the vent valve is inoperable.

For any condition where more than one of the eight solenoid vent valves are inoperable, entry into ACTION 20 is required.

i ACTION STATEMENTS i

ACTION 13 -

With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE 1

status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 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 ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for I

surveillance testing per Specification 4.3.2.1.1 provided the other channel is OPERABLE.

ACTION 14 -

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.

I hour.

ACTION 15 -

NOT USED 1

ACTION 16 -

With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the I

inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is demonstrated by CHANNEL CHECK within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; one additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per specification 4.3.2.1.1.

ACTION 17 -

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

ACTION 18 -

With the 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 j

following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

l SALEM - UNIT 2 3/4 2-22 Amendment No.121 l

TABLE 3.3-3 (Continued)

ACTION 19 -

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:

t The inoperable channel is placed in the tripped a.

condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l l

b.

The Minimum Channels OPERABLE requirements is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

ACTION 20 -

With the number of OPERABLE channels one less than the Tetal Number of Channels, restore the inoperable channel to operable l

status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 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 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 to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification'4.3.2.1.1

[

provided the other channel is OPERABLE.

ACTION 21 -

With the number of OPERABLE channels one less than the Minimum i

Number of Channels, operation may proceed provided that either:

a,

'.?he inoperable channel is restored to OPERABLE within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

b.

If the affected Main Feedwater Pump is expected to be out of service for more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the inoperable channel is jumpered so as to enable the Start Circuit of the

l Auxiliary Feedwater Pumps upon loss of the other Main Feedwater Pump.

ACTION 22 -

With the Number of OPERABLE channels relating directly with the number of OPERABLE Auxiliary Feedwater Pumps, the ACTIONS of L.C.O.

3.7.1.2 apply.

r ACTION 23 -

With the Number of OPERABLE channels one less than the Total L

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 HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

t SALEM - UNIT 2 3/4 3-23 Amendment No.121 i

g TABLE 4.3-2

'E f

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS e5

[

CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 1.

SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION a.

Manual Initiation N.A.

N.A.

R 1,2,3,4 b.

Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4 c.

Containment Pressure--High S

R Q(3) 1,2,3 l

d.

Pressurizer Pressure--Low S

R Q

1,2,3 l

e.

Differential Pressure S

R

-Q 1,2,3 y

Between Steam Lines--High d

i f.

Steam Flow in Two Steam S

R Q

1,2,3 l

Lines--High coincident with Tavg--Low-Low or Steam Line Pressure--Low 2.

CONTAINMENT SPRAY a.

Manual Initiation N.A.

N.A.

R 1,2,3,4 b.

Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4 c.

Containment Pressure--High-S R

Q(3) 1,2,3 f

3 High d

k ELo Y

e -

4.-

TABLE 4.3-2 (Continued) e-9 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS E

-4 CHANNEL MODES IN WHICH N

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE I

FUNCTIONAL UNIT CHECK-CALIBRATION TEST REOUIRED 3.

CONTAINMENT ISOLATION a.

Phase "A"

Isolation

1) Hanual N.A.

N.A.

R 1,2,3,4 2)

From Safety Injection N.A.

N.A.

M(2) 1,243,4 Automatic Actuation Logic y

b.

Phase."B" Isolation a

y 1)

Manual N.A.

N.A.

R 1,2,3,4 W

2) Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4

3) Containment Pressure--

S R

Q(3) 1,2,3 l

High-High c.

Containment Ventilation Isolation

1) Manual N.A.

N.A.

R 1,2,3,4

2) Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3,4

3) Containment Atmosphere Per table 4.3-3 Gaseous Radioactivity-High 4

a 2

E F.

1

..-,,..-__.---.,x-,.

,m

..-_..,..m-

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

TABLE 4.3-2 (Continuedi

?

SE ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS 5

CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 4.

STEAM LINE ISOLATION a.

Manual N.A.

N.A.

R 1,2,3 b.

Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3 c.' Containment Pressure--

S R

Q(3) 1,2,3 l

High-High d.

Steam Flow in Two Steam S

R Q

1,2,3 f

M Lines--High coincident with Tavg--Low-Low or Y

Steam Line Pressure--Low t

5.

TURDINE TRIP AND FEEDWATER ISOLATION 9

i a.

Steam Generator Water S

R Q

1,2,3 Level--High-High 6.

SAFEGUARDS EQUIPMENT CONTROL SYSTEM (SEC) LOGIC a.

Inputs N.A.

N.A.

M(6) 3,2,3,4 b.

Logic, Timing and Outputs

N.A.

N.A.

M(1)

I,2,3,4 7.

UNDERVOLTAGE, VITAL BUS g

Eg a.

Loss of Voltage S

R H

1,2,3 A

g b.

Sustained Degraded Voltage S

R H

1,2,3 w

H

TABLE 6.3-2 (Continued)

E h

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS E-

~

-4 CHANNEL MODES IN WHICH N

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CIIECK CALIBRATION TEST REOUIRED 8.

AUXILIARY FEEDWATER Automatic Actuation Logic N.A.

N.A.

M(2) 1,2,3 a.

b.

Manual Initiation N.A.

N.A.

M(5) 1,2,3 c.

Steam Generator Water S

R Q

I,2,3 l

t Level--Low-Low d.

Undervoltage - RCP S

R Q

1,2 l

w1 e.

S.I.

See 1 above (All S.I.

surveillance requirements) y M

f.

Trip of Main N.A.

N.A.

S/U(4) 1,2 Feedwater Pumps g.

Station Blackout See 6 and 7 above (SEC and U/V Vital Bus) 9.

SEMIAUTOMATIC TRANSFER TO RECIRCULATION a.

RWST Low Level S

R Q

1,2,3 b.

Automatic Initiation Logic N.A.

N.A.

1,2,3,4

{

a R

A N

l

3/4.3 INSTRUMENTATION BASES

==================================================================

I 3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP)

INSTRUMENTATION l

The OPERABILITY of the protective and ESF instrumentation systems and interlocks ensure that 1) associated ESF action and/or reactor trip will u.

be initiated when the pa 4?" 2r monitored by each channel or combination thereof exceeds its setpo4at, 2) the specified coincidence logic and sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance consistent with maintaining an appropriate level of reliability of the Reactor Protection and Engineered Safety Features j

instrumentation and, 3) sufficient system functions capability is available f

from diverse parameters.

{

i The OPERABILITY of these systems is required to provide the overall j

reliability, redundance and diversity assumed available in the facility design l

for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses.

The surveillance requirements specified for these systems ensure that the i

overall system functional capability is maintained comparable to the original design standards. The periodic surveillance testa performed at the minimum I

frequencies are sufficient to demonstrate this capability.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP-10271, " Evaluation of Surveillance I

Frequencies and Out of Service Times for the Reactor Protection Instrumentation System," and Supplements to that report.

Surveillance intervals and out of service times were determined based on maintaining an appropriate level of reliability of the Reactor Protection System and Engineered Safety Features instrumentation.

The measurement of response time at the specified frequencies provides assurance that the protective and ESF action function associated with each channel is completed within the time limit assumed in the accident analyses.

No credit was taken in the analyses for those channels with response times indicated as not applicable.

Response time may be demonstrated by any series of sequential, I

overlapping or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test i

J measurements or 2) utilizing replacement sensors with certified response times.

I 3/4.3.3 MONITORING INSTRUMENTATION 3/4.3.3.1 RADIATION HONITORING INSTRUMENTATION The OPERABILITY of the radiation monitoring channels ensures that 1) the radiation levels are continually measured in the areas served by the individual channels and 2) the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded.

SALEM - UNIT 2 B 3/4 3-1 Amendment No. 121

ML20056F022

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