Text

Amend 36 to License NPF-86,revising TS to Allow Longer Surveillance Test Intervals & AOTs for RPS & ESFAS & Removing Requirement to Perform RTS Analog Channel Operational Test on Staggered Basis
	ML20082H949
Person / Time
Site:	Seabrook
Issue date:	04/10/1995
From:	Mckee P; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20082H953	List: ML20082H949; ML20082H955;
References
	NUDOCS 9504170446
	Download: ML20082H949 (30)
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.f, t.

4 *,.

. UNITED STATES I

S NUCLEAR REGULATORY COMMISSION

i j

WASHINGTON, D.C. 20686-0001.

. \\, *****/

j NORTH ATLANTIC ENERGY SERVICE CORPORATION. ET AL*

DOCKET NO. 50-443 SEABROOK STATION. UNIT NO. 1

^

AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 36 License No. NPF-86 1.

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

A.

The application for amendment by North Atlantic Energy Service Corporation, et al. (the licensee), dated April-23, 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; 8.

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; 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.

North Atlantic Energy Service Company (NAESCO) is authorized to act as agent for the:. North Atlantic Energy Corporation, Canal Electric-Company, The Connecticut Light and. Power Company, Great Bay Power Corporation, Hudson Light and Power Department, Massachusetts Municipal Wholesale Electric Company, Montaup Electric Company, New England Power Company, New Hampshire Electric Cooperative, 'Inc., Taunton Municipal Light Plant, and The United Illuminating Company..and has exclusive responsibility and control over the physical construction, operation, and maintenance of the facility.

9504170446 950410 DR ADOCK 0500 3

i

,, ^.

a u..:

q 2.

Accordingly, the licuse is amended by changes to the Technical l

Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2)-of Facility Operating License No. NPF-86 is hereby amended to read as follows:

(2) Technical Soecifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 36, and the Environmental Protection Plan contained in Appendix B are incorporated into Facility License No.

NPF-86. NAESCO shall operate the facility in accordance with the Technical Specifications and the Environmental. Protection Plan.

3.

This license amendment is effective as of the date of its issuance, to be implemented within 60 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION j

l Phillip F. McKee, Director Project Directorate I-3 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation i

Attachment:

Changes to the Technical Specifications Date of Issuance: April 10, 1995

a

-.i -

I ATTACHMENT TO LICENSE AMENDMENT NO. 36 i

FACILITY OPERATING LICENSE NO. NPF-86 DOCKET NO. 50-443 4

Replace the following pages of Appendix A, Technical Specifications, with the j

attached pages as indicated. The revised pages are identified by amendment number and contain vertic l lines indicating the areas-of change. Overleaf pages have been provided.p Remove Insert 3/4 3-1*

3/4 3-17 3/4 3-2 3/4 3-2 3/4 3-3 3/4 3-3.

3/4 3-4 3/4 3-4 3/4 3-5 3/5 3-5 3/4 3-6 3/5 3-6 3/4 3-9 3/4 3-9 3/4 3-10 3/4 3-10 3/4 3-13 3/4 3-13 3/4 3-14*

3/4 3-14*

3/4 3-15*

4 3/4 3-16 3/4 3-16 3/4 3-19 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 3/4 3-24*

3/4 3-24*

3/4 3-31 3/4 3-31

~. _

r"'--

lip l

.~

/

i.1, 3/4 3-32

'3/4'3-32 3/4 3-33 3/4 3-33 3/4 3-34

.-3/4 3-34 3/4 3-35

'3/4 3 3/4 3-36*'

3/4 ?J36*

B 3/4 3 B 3/4 3-1 B 3/4 3-2*

B 3/4 3-2*'

l 1

I 1

h-.

I o

o

3/4.3 INSTRUMENTATION

}/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION e

('-

3.3.1 As a minimum, the Reactor Trip System instrumentation channels and interlocks of Table 3.3-1 shall be OPERABLE.

APPLICABILITY: As shown in Table 3.3-1.

ACTION:

As shown in Table 3.3-1.

SURVEILLANCE REOUIREMENTS 4.3.1.1 Each Reactor Trip System instrumentation channel and interlock and the automatic trip logic shall be demonstrated OPERABLE by the performance of the Reactor Trip System Instrumentation Surveillance Requirements specified in Table 4.3-1.

4.3.1.2 The REACTOR TRIP SYSTEM RESPONSE TIME of each Reactor trip function shall be demonstrated to be within its limit at least once per 18 months.

Each test shall f aclude at least one train such that both trains are tested at least once per 36 months and one channel per function such that all channels are 1

tested at least once every N times 18 months where N is the total number of redundant channels in a specific Reactor trip function as shown in the " Total No. of Channels" column of Table 3.3-1.

l SEABROOK - UNIT 1 3/4 3-1

y TABLE 3.3-1 e

REACTOR TRIP SYSTEN INSTRistENTATION i

NINIORIN TOTAL NO.

CHAlelELS CHANNELS APPLICABLE g

FUNCTIONAL UNIT OF CHAlglELS TO TRIP OPERABLE HODES g;LMg z

l 1.

Manual Reactor Trip 2

1 2

1, 2 -

'l

~

2

'1 2

3*, 4*, 5*

10 2.

Power Range, Neutron Flux.

a.

High Setpoint 4

2 3

1, 2 2

b.

Low Setpoint 4

2 3

l###, 2 2

3.

Power Range, Neutron Flux 4

2-3

-1, 2

2 High Positive Rate R

4.

Power. Range, Neutron Flux, 4

2 3

1, 2 2

High Negative Rate i'

5.

Intermediate Range, Neutron Flux 2

1 2

1###, 2 3

6.

Source Range, lieutron Flux a.

Startup 2

1 2

2##

'4-b.

Shutdown 2

0 1

3,4,5 5

c.

Shutdown 2

1 2

3*,

4*,'5*

-10 7.

Overtemperature AT 4

2 3

1, 2 6

8.

Overpower AT 4

2 3

1, 2 6

f 9.

Pressurizer Pressure--Low 4.

2 3

'l**

6 b

10. Pressurizer Pressure--High-4 2

3 1, 2 6.

E

11. Pressurizer Water Level--High.

3 2

2 1**

6#

g 5

~

a

" s..:

. s t.

~

9 TABLE 3.3-1 (Continued)

E.J REACTOR TRIP SYSTEM INSTRUMENTATION

~

MINIMUM E

TOTAL NO.

CHANNELS

' CHANNELS APPLICA8LE Q

FUNCTIONAL UNIT OF CHM 0lELS TO TRIP OPERABLE MODES ACTION

~

12. Reactor Coolant Flow--Low a.

Single Loop (Above P-8) 3/ loop 2/ loop in 2/ loop in 1

.6#

l any oper.

each oper-ating loop ating loop b.

Two Loops (Above P-7 and 3/ loop

-2/ loop in 2/ loop 1

6#

l-

~

below P-8) two oper-each oper-

~

ating loops ating loop

13. Steam Generator Water 4/sta. gen.

2/sta. gen.

3/sta. gen.

1, 2.-

6 1

Level--Low--Low in any oper-each oper-

.. l -l w

ating sta.

ating stm.

w O

9en.

gen.

14. Undervoltage--Reactor Coolant 4-2/ bus 2-1/ bus 2 on one bus 1**-

6 Pumps

15. Underfrequency--Reactor Coolant 4-2/ bus 2-1/ bus 2 on one bus 1**

6

-Pumps

16. Turbine Trip

.l a.

Low' Fluid Oil Pressure

.3 2

2 1***-

'6#

g b.

Turbine Stop Valve Closure 4

~ 4 4

- l***

11

=g

17. Safety Injection Input from ESF 2

1 2

1, 2 7

. l 3e i

18. Reactor Trip System Interlocks a.

Intermediate Range M

Neutron Flux, P-6' 2

1 2

2##-

8 4

w.

,w

,emo v

m '"

e u,j TABLE 3.3-1 (Continued) f REACTOR TRIP SYSTEM INSTRUMENTATION NININUN' l

E TOTAL NO.

CHANNELS CHANNELS ~

APPLICABLE Q

FUNCTIONAL UNIT OF CHAlffELS TO TRIP OPERABLE MODES ACTION

~

18.

b.

Low Power Reactor Trips Block, P-7 P-10 Input 4

2 3

1 8

or P-13 Input 2

1 2

1 8

c.

Power Range Neutron Flux, P-8 4

2 3

1 8'

d.

Power Range Neutron 4

2 3

1 8

w2 Flux, P-9 wi e.

Power Range Neutron Flux, P-10 4

2 3

1 8

f.

Turbine Impulse Chamber Pressure, P-13 2

1 2

l' 8

19. Reactor Trip Breakers 2

1 2

1, 2 9, 12 2

. 1 2

3*, 4*, 5*

10

20. Automatic Trip and Interlock 2

1 2

1, 2 7

l-Logic 2

1 2

3*, 4*, 5*

10

$i

?.

.A-s w-kv e..-

a

TABLE 3.3-1 (Continuedi TABLE NOTATIONS

When the Reactor Trip System breakers are in the closed position and the Control Rod Drive System is capable of rod withdrawal.

- Trip function automatically blocked or bypassed below the P-7 (At Power)

Setpoint.

- - Trip function automatically blocked below the P-9 (Reactor Trip / Turbine Trip l

Interlock) Setpoint.

The provisions of Specification 3.0.4 are not applicable.

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

1. 1. Below the P-10 (Low Setpoint Power Range Neutron Flux Interlock).Setpoint.

]

i ACTION STATEMENTS ACTION 1 - 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 be in HOT STAN08Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 2 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable Channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

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, and

c. Either, THERMAL POWER is restricted to less than or equal to 75% of RATED THERMAL POWER and the Power Range Neutron Flux i

Trip Setpoint is reduced to less than or equal to 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 per Specification 4.2.4.2.

SEABROOK - UNIT 1 3/4 3-5 Amendment No. 36

a TABLE 3.3-1 icontinuedi ACTION STATEMENTS (Continued)-

i

-ACTION 3 - With the ' number of channels OPERABLE 'one less than the' Min'imum Channels OPERABLE requirement and with the THERMAL POWER level:

a.:Below the P-6 (Intermediate Range Neutron Flux Interlock)

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

b. Above the P-6 (Intermediate Range Neutron Flux Interlock)'

Setpoint.but below 105 of RATED THERMAL POWER, restore the inoperable channel-to 0PERABLE~ status prior to increasing THERMAL POWER above 10% of RATED THERMAL POWER.

l ACTION 4 - With the number of OPERA 8LE channels one less than the Minimum-Channels OPERABLE requirement, suspend all operations involving positive reactivity changes.

ACTION 5 - With the number of OPERABLE channels one less than the Minimum Channels OPERA 8LE' 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 System-breakers, suspend all operations. involving positive reactivity -

changes and verify that valve RMW-V31 is closed and secured in position within the next hour.

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:

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 , and

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 otherLchannels per Specification 4.3.1.1.

ACTION 7 - With the number of OPERA 8LE 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 STAND 8Y within 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 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, provided the other channel is OPERA 8LE.

ACTION 8 - With less than the Minimus Number of Channels OPERABLE, within I hour determine by observation of the associated permissive annunciator window (s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

4

'}

4 SEABROOK - UNIT 1 3/4 3-6 Amendment No. 36

l R

TABL 4.3-1 E

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS k

TRIP ANALOG ACTUATING MODES FOR E

CHANNEL DEVICE WHICH w

CHANNEL CHANNEL OPERATIONAL OPERATIONAL - ACTUATION SURVEILLANCE-FUNCTIONAL UNIT CHECK CALIBRATION TEST

. TEST LOGIC TEST IS REQUIRED

~

1.

Manual Reactor Trip N.A.

N.A.

R(13)

N.A.

'1,2,3*,4*,5*

2.

Power Range, Neutron Flux a.

High Setpoint S

D(2, 4),

Q N.A.

N.A.

1, 2 l.

M(3,4),

Q(4,6),

R(4,'5) b.

Low Setpoint

' S R(4)

S/U(1)

N.A.

-1***, 2-i 3.

Power Range, Neutron Flux, N.A.

R(4)

Q N.A.

- N.A.

1, 2 l

y High Positive Rate e

4.

Power Range, Neutron Flux, N.A.

R(4)

Q N.A.

N.A.

1, 2

-l High Negative Rate 5.

Intermediate Range, S

R(4,5)

S/U(1)

N.A.

1***, 2.

Neutron Flux 6.

Source Range, Neutron Flux S

R(4, 5)

S/U(1),Q(9)

N.A.

'2**,

3,.4,-5 7.

Overtemperature AT S

- R Q

N.A.

1, 2 k

8.

Overpower AT S

R Q

N.A.

1, 2 -

k 9.

Pressurizer Pressure--Low S

R

-Q N.A.

N.A.

'l i

10.. Pressurizer Pressure--High S

Rl

- Q N. A'.

N.A.

'1, 2

?

11. Pressurizer Water Level--High S R

" Q' N.A.

N.A.

1-

12. Reactor Coolant Flow--Low S

R Q

N.A.

_ N.A.

l_

t.

.m

.m z

- m.m.

..m..m--.

..m 2 m m

e.

+

-+ -

mg TABLE 4.3-1 (Continued) m REACTOR TRIP SYSTEN INSTRUMENTATION SURVEILLANCE REQUIREMENTS TRIP g

ANALOG ACTUATING MODES FOR q

CHANNEL DEVICE WHICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLAtiCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED

13. Steam Generator Water Level-- S R

Q N.A.

N.A.

1, 2 l

Low-Low

14. Undervoltage - Reactor Coolant N.A.

R N.A.

Q N.A.

1 l

Pumps

15. Underfrequency - Reactor N.A.

R N.A.

Q N.A.

1 l

Coolant Pumps w

a w

16. Turbine Trip E

a.

Low Fluid Oil Pressure N.A.

R N.A.

S/U(1,10)

N.A.

I b.

Turbine Stop Valve N.A.

R N.A.

S/U(1,10)

N.A.

I

17. Safety Injection Input from N.A.

N.A.

R N.A.

1, 2 ESF

18. Reactor Trip System Interlocks a.

intermediate Range Neutron Flux, P-6 N.A.

R(4)

R N.A.

N.A.

2**

b.

Low Power Reactor g

Trips Block, P-7 N.A.

R(4)

R N.A.

N.A.

1 A

c.

Power Range Neutron g

Flux, P-8 N.A.

R(4)

R N.A.

N.A.

1-g d.

Power Range Neutron Flux, P-9 N.A.

R(4)

R N.A.

N.A.

1 R

m m

--e

~

f 2

-2 a-

. - m.-

c

m i

i., '

TABLE 4.3-1 (Continued)

TABLE NOTATIONS (Continued)

(12)'~ Number not used.

~

(13) The TRIP ACTUATING DEVICE OPERATIONAL TEST shall independently verify the OPERA 8ILITY of the undervoltage and shunt trip circuits for the l

Manual Reactor Trip Function. The test shall also verify the OPERA 8ILITY of the Bypass Breaker trip circuit (s).

(14) Local manual shunt trip prior to placing breaker in service.

(15) Automatic undervoltage trip.

I J

1

~

l SEABROOK - UNIT 1 3/4 3-13 Amendment No. 36

1 INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION,

LIMITING CONDITION FOR OPERATION-3.3'2.The Engineered Safety' Features Actuation System (ESFAS) instrumentation channels and ' nterlocks 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.

APPLICABILITY: 4s shown in Table 3.3-3.

I ACTION:

a.

With an ESFAS Instrumentation or Interlock Trip Setpoint trip less-conservative than the value shown in the Trip Setpoint column but-more conservative than the value shown in the Allowable Value column of Table 3.3-4, adjust the Setpoint consistent with the Trip Satpoint value.

b.

With an ESFAS Instrumentation or Interlock Trip Setpoint less -

conservative than the value shown in the Allowable Value column.of.

Table 1.3-4, either:

t 1.

Adjust the Setpoint consistent with the Trip.Setpoint value of Table 3.3-4, and determine within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that Equation 2.2-1 was satisfied for the affected channel, or 2.

Declare the channel inoperable and apply the applicable ACTION statement requirements of Table 3.3-3 until the channel is restored to OPERA 8LE status with its Setpoint adjusted consistent with the Trip Setpoint value.

Equation 2.2-1 Z + R + S s TA Where:

Z = The value from Column Z of Table 3.3-4 for the affected a

channel, R = The "as measured" value (in percent span) of rack error for the affected channel, S = Either the "as measured" value (in percent-span) of the sensor error, or the value from Column S (Sensor Error) of Table 3.3-4 for the affected channel, and TA = The value from Column TA (Total Allowance) of Table 3.3-4 for the affected channel.

c.

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

~

SEABROOK - UNIT 1 3/4 3-14

INSTRUMENTATION-ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS 4.3.2.1 Each ESFAS instrumentation channel and interlock and the automatic actuation logic and relays shall be demonstrated OPERABLE by performance of the ESFAS Instrumentation Surveillance Requirements specified in Table 4.3-2.

4.3.2.2..The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstriated to be within the limit at-least once per 18 months.

Each test shall include at least one train such that both trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once per N times 18 months 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.

4 J

SEABROOK - UNIT 1 3/4 3-15

g TABLE 3.3-3 co ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRLMENTATION MINIMUM g

TOTAL NO.

CHANNELS CHANNELS APPLICABLE-q FUNCTIONAL UNIT OF CHAletELS TO TRIP OPERABLE NODES ETimi

~

1.

Safety Injection (Reactor Trip, Feedwater Isolation, Start Diesel Generators, Phase "A" Isolation, Containment Ventilation Is01ation, Emergency Feedwater, Service Water to Secondary Component Cooling Water Isolation, CBA Emergency Fan / Filter w3 Actuation.and Latching Relay).

l w

l E

a.

Manual Initiation 2_

1 2

1, 2, 3, 4 17 b.

Automatic Actuation 2

1 2

1, 2,-3, 4 13 l

Logic and Actuation j

Relays c.

Containment 3

2 2'

1, 2, 3 '

18*

l Pressure--Hi-1 l

l d.

Pressurizer 4

2 3

1, 2, 3#

18-Pressure--Low g

l h

e.

Steam Line 3/ steam line 2/ steam line-2/ steam line 1, 2, 3#

18*-

l g

Pressure--Low any steam r+

line -

E L

e v

v

=y n..-

,u

~

3:

~w L

- M.

TABLE 3.3-3 (Continued) s ENGINEERED SAFETY FEATbRES ACTUATION SYSTEM INSTRUMENTATION k

MINIMUM TOTAL NO.

CHANNELS CHAletELS APPLICABLE-FUNCTIONAL UNIT OF CHANNELS TO TRIP 9PERABLE MODES-ACTION cg 4.

Steam Line Isolation (continued) b.

Automatic Actuation 2

1 2

1, 2,- 3 20

~

Logic and Actuation Relays c..

Containment Pressure--

3 2

2 1,2,3 18*

j..

Hi-2 d.

Steam Line 3/ steam line 2/ steam line 2/ steam line 1, 2, 3#

18*

. ]

Pressure-Low any steam

~

.line e.

Steam Generator

-Pressure - Negative 3/ steam line 2/ steam line 2/ steam line 3**

18*

l' ;;

Rate-High any steam e

line 5.

Turbine Trip a.

Automatic Actuation-2-

1 2

- 1, 2 22 Logic and Actuation Relays b.

Steam Generator

'4/sta.; gen.

2/sta. gen.

3/sta. gen.

1, 2

'18 Water Level--

k High-High (P-14)

E R

6.

Feedwater Isolation

a. ' Steam Generator Water 4/sta. gen.

-2/sta. gen.

3/sta. gen.-

1, 2 -

18 4

z Level--High-High (P-14) w b.

Low RCS T Coincident 4

2 3

1, 2

.18 withReacNrTrip

. ~

V v,g TABLE 3.3-3 (Continued) co ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION MINIMUM E

TOTAL NO.

CHANNELS CHANNELS APPLICABLE p

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

~

c.

Safety Injection SeeItem1.aboveforallSafetyInjectioninitiatIngfunctions and requirements.

7.

Emergency Feedwater a.

Manual Initiation (1) Motor driven pump 1

1 1

1, 2, 3 21 (2) Turbine driven pump 2

1 2

1, 2, 3 21' w

b.

Automatic Actuation Logic 2

1 2

1, 2, 3 20 and Actuation Relays w

A, c.

Sta. Gen. Water Level--

Low-Low Start Motor-Driven Pump 4/sta. gen.

2/sta. gen.

3/sta. gen. 1, 2, 3 18 and Start Turbine -

Driven Pump d.

Safety Injection Start Motor-Driven Pump See Item 1. above for all Safety Injection initiating functions-and and Turbine-Driven Pump requirements.

i e.

Loss-of-Offsite Power l

Start Motor-Driven See Item 9 for Loss-of-Offsite Power initiating functions and l

Pump and Turbine-requirements.

l Driven Pump 8.

Automatic Switchover to Containment Sump a.

Automatic Actuation 2_

1 2

1, 2, 3, 4 13 Logic and Actuation Relays

~.

g-v, S

TABLE 3.3-3 (Continued)

=

ENGItNRED SAFETY-FEATURES ACTUATION SYSTEN INSTRLMENTATION i

i NININUN

~

.g TOTAL NO.

CHANNELS CHANNELS APPLICABLE q

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

~

b.

RWST Level--Low-Low 4

2 3

1, 2, 3, 4 -

18 g

Coincident With:

t Safety Injection See Item 1. above for all Safety Injection initiating functions

'I

+

and requirements, t

9.

Loss of' Power (Start t

Emergency Feedwater) w a.

4.16-kV' Bus E5 and E6-2/ bus 2/ bus 1/ bus 1, 2, 3, 4 14 l

l 1

Loss of Voltage w4 b.

4.16 kV Bus E5 and E6-

~

Degraded Voltage 2/ bus 2/ bus 1/ bus 1, 2, 3, 4 14

-l

. Coincident with SI See item 1. above for all Safety Injection initiating functions-and requirements.

10. Engineered Safety Features Actuation System Interlocks a.

Pressurizer Pressure, 3

2 2

1, 2, 3 19

-P-Il b.

Reactor Trip, P-4 2

2 2

1, 2, 3 21 c..

Steam Generator Water 4/sta. gen.

2/sta. gen.

3/sta. gen. 1,-2, 3 18 Level, P-14

?.

t t

?

n

p.

TABLE 3.3-3"(Continued)

' TABLE NOTATIONS

~ *The provisions of Specification 3.0.4 are not applicable.

' # Trip function may be blocked in' this MODE below the P-11.(Pressurizer.

Pressure Interlock) Setpoint.

- Trip function automatically blocked above P-11' and may be blocked below P-ll when Safety Injection on low steam line pressure is not blocked.

ACTION STATEMENTS ACTION 13

'With the number of OPERABLE channels one less than.the Minimus '

Channels OPERABLE requirement, be in at least HOT STAN08Y within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-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 surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

ACTION 14 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may. proceed -

provided the following conditions are satisfied:

.a.. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and-b.

The Minimum Channels OPERABLE requirements is met'; however, the inoperable channel may be bypassed for up to-2 hours for surveillance testing of other channels per. Specification 4.3.2.1.

ACTION 15 - 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 met. One additional channel may -

1 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 l

Specification 4.3.2.1.

ACTION 16 - With less than the Minimus Channels OPERABLE requirement, operation may continue provided the containment purge supply and exhaust valves are maintained closed.

ACTION 17 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERA 8LE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at-least HOT STAND 8Y 4

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 .

ACTION 18 - 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:

SEABROOK - UNIT 1 3/4 3-22 Amendment No. 36 n

..n c

. 6..

TABLE 3.3-3 (Continued)

I

. ACTION STATEMENTS-(Continued) 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 , and ll 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 l_

survalliance testing of other channels per Specification 4.3.2.1.

4 ACTION 19 - Wit,h less than the Minimus Number of Channels OPERABLE,- within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months determine by observation of the' associated permissive annunciator window (s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

ACTION 20 - With the number of OPERA 8LE channels one less than the Minimum Channels' OPERA 8LE 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 H0T STAND 8Y 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

-provided the other channel is OPERABLE.

ACTION 21 - With the number of OPERABLE channels one less than the Total

. Number of Channels, restore the inoperable channel to GPERABLE.

. status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STAND 8Y within 6"'

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

ACTION 22 - With the nuther of OPERA 8LE channels one less than the Minimum Channels OPERA 8LE requirement, restore the inoperable channel to OPERA 8LE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT STAN08Y within 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 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 provided the other. channel is OPERA 8LE.

ACTION 23 - With the number.of OPERA 8LE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

j SEABROOK - UNIT 1 3/4 3-23 Amendment No. 36 w

,w--.m-a e

~

w

--r-v

m j

TABLE 3.3-4 f

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS SENSOR E

TOTAL ERROR Q

FUNCTIONAL UNIT ALLOWANCE fTA) Z (Si TRIP SETPOINT ALLOWABLE VALUE-1.

Safety Injection (Reactor Trip, Feedwater Isolation, Start Diesel Generator, Phase "A" Isolation, Containment Ventilation Isolation, and Emergency Feedwater, Service Water to Secondary Component Cooling Water Isolation, C8A Emergency Fan / Filter Actuation, and Latching Relay).

w1 a.

Manual Initiation N.A.

N.A.

b.

Automatic Actuation Logic N.A.

N.A.

c.

Containment Pressure--Hi-1 4.2 0.71 1.67 s 4.3 psig s 5.3 psig d.

Pressurizer Pressure--Low N.A.

N.A.

1 1800 psig 2 1786 psig l

e.

Steam Line Pressure--Low 13.1 10.71 1.63 2 585 psig 2 568 psig*

~

2.

Containment Spray a.

Nanual Initiation N.A.

N.A.

g b.

Automatic Actuation Logic N.A.

N.A.

3g and Actuation Relays E

c.

Containment Pressure-Hi-3 3.0 0.71 1.67 5 18.0 psig s 18.7 psig 5

-.x

.n 1

. l..

. y TABLE'4.3-2 m

B ENGINEERED SAFETY F EATUES ACT ATI0fl SYS"EN INSTRl3tENTATION R

SJ IVEI

- JUIC E lf0UIIENEN S

TRIP E

-ANALOG ACTUATING NODES-Q-

CHANNEL DEVICE NASTER SLAVE FOR WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION-. RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST 'IESI IE11 IS REQUIRED

1. Safety Injection (Reactor Trip, l Feedwater Isolation Start Diese g

Generator, Phase "A Isolation ContainmentVentilationIsolation, and Emergency Feedwater, Service Water Water Isolation,ponent Cooling to Secondary Com CBA Emergency r

Fan / Filter Actuation, and Latching Relay).

i w

C

a. Manual' Initiation M.A.

N.A.

R N.A.

N.A.

1,2,3,:4 b

b. Automatic Actuation N.A.

N.A.

N(1)

N(1)-

Q

1. 2, 3, 4 Logic and Actuation i

Relays

c. Containment Pressure-S R

Q N.A.

N.A.

1, 2, 3 l

Hi-1

d. Pressurizer Pressure S

R Q

N.A.

1, 2, 3

-l Low

e. Steam Line S

R

-Q N.A.

N.A.

1, 2, 3-l Pressure-Low k

2. Containment Spray

=

k

a. Manual Initiation N.A.

-N.A.

M. A..

R N.A.

N.A.

1, 2,.3, 4'

=.

c E

b.-Automatic Actuation N.A.

N.A.

.N.A.

N.A.

N(1)

Q 1,.2,:3, 4 Logic and Actuation g

Relays C. Containment Pressure-S R

Q

~N.A.

N.A.

N. A.'

N.A.

1,-2, 3.

((

Hi-3

.~

I d

TABLE 4.3-2 (Continued)

- [s

~

.m E

ENGINEERED SAFETY P EATUt ES A:TUATI0d SYS"EN INSTRUMENTATION -

ElyEI

. JUIC E REOUI tEMENS TRIP ANALOG ACTUATING MODES E

CHANNEL DEVICE MASTER SLAVE FOR WHICH Q

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCEL FUNCTIONAL UNIT CHECK-CALIBRATION TEST TEST LOGIC TEST.IEST IISI IS REQUIRED

3. Containment Isolation

a. Phase "A" Isolation

1) Manual Initiation N.A.

N.A.

R N.A.

' N.A.

N.A.

-1, 2, 3, 4

2) Automatic Actuation M.A.

N.A.

M(1)

Q

_ 1, ' 2,: 3. Logic and Actuation Relays

3) Safety Injection See Item 1. 'above for all Safety Injection Surveilla,.m Requirements, w

b. Phase "B" Isolation U

1) Manual Initiation -

N.A.

~ N.A.

R N.A.

N.A.

N. A.~

l',

2, 3, 4 -

2) Automatic Actuation 'N.A.

N.A.

M(1)-

M(1)

Q 1, 2,13, 4-Logic Actuation Relays l

3) Containment S

R Q

N.A.

- N.A.

N.A.

1, 2, 3 l ~

-Pressure-Hi-3

c. Containment Ventilation Isolation

1) Manual Initiation N.A.

N.A.

R N.A.

N.A.

1, ?,. 3,.4

~

1, 2, 3, 4

2) Automatic Actuation N.A.

N.A.

g logic and Actuation

. N(1)

M(1)

Q

=

t Relays

,e g

3) Safety Injection See Item 1. above for all' Safety Injection Surveillance Requirements.

4) Containment On Line 'S R-Q(2)

- N.A.

N.A.

1, 2,.3, 4 w

Purge. Radioactivity-High i

nr

-- ve %'

vt v.

<c e'

e'w t's.

era

u

-w

--n=

w c

m t

a -

~

vi TABLE 4.3-2 (Continued) 9 E

ENGINEERED SAFETY F EATUt ES A:T. ATION SYS"EM INSTRtMENTATION

~

p 5 J (VEI

-.AN: E LEQUI lENENS l

i TRIP i

e ANALOG ACTUATING MODES CHANNEL DEVICE MASTER SLAVE FOR WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONA. UNI CHECK CALIBRATION TEST TEST LOGIC TEST 115I

]LSI IS REOUIRED

4. Steam.ine solation l

a. Manual Initiation N.A.

N.A.

R

-N.A.

N.A.

l. 2, 3 (SystemD

b. Automat'ic Actuation N.A.

N.A.

M(1)

Q 1,

,3 Logic and Actuation Relays

c. Containment Pressure-S R

Q N.A.

N.A.

1, 2,- 3 _

l Hi-2

d. Steam Line S

R Q

N.A.

1, 2, 3 l

.t' Pressure-Low

e. Steam Line Pressure-S R

Q N.A.

N.A.

3 l

Negative Rate-High w

w

5. Turbine Trip

a. Automatic Actuation N.A.

N.A.

M(1)

Q 1, 2 Logic and Actuation Relays

b. Steam Generator Water S

R Q

N.A.

1, 2

-l Level-High-High (P-14)

6. Feedwater' Isolation

a. Steam Generator Water S

R Q

N.A.

1, 2 l

Level--High-High (P-14) S a-5

b. Low RCS T Coincident R

Q N. A..

N.A.

N. A.-

1, 2 l

E with Reac Nr Trip 5

c. Safety Injection See Item 1. above for all Safpty Injection Surveillance Requirements.

7. Emergency Feedwater

O

a. Manual Initiation Il Motor-driven pump N.A.

N.A.

R N.A.

N.A.

1, 2, 3

2) Turbine-drivenpump N.A.

N.A.

R N.A.

N.A.

1, 2, 3

'N

.w v.

E' TABLE 4.3-2 (Continued) ce l

ENGINEERED SAFETY t EATUt ES ACT JATI0fi SYT"EM INSTRtMENTATION SJ IVEI

..ANCE tEOUIl ENEFS I

c TRIP-2 ANALOG ACTUATING MODES U

CHANNEL

. DEVICE-MASTER SLAVE FOR WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE.

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IESI IESI IS REQUIRED

7. Emergency Feedwater (Continued)

b. Automatic Actuation N.A.

N.A.

'N.A.

N.A.

N(1)

M(1)'

Q 1, 2, ' 3 and Actuation Relays 1

c. Steam Generator Water S

R Q

- N.A.

N.A.

N. A. ' 1, 2,.3 ll Level-Low-Low, Start Motor-Driven Pump and Turbine-Driven Pump w1

d. Safety Injection, Start See Item 1. above for all-Safety Injection Surveillance Requirements.

Motor-Driven Pump and w

4.

-Turbine-Driven Pump

e. Loss-of-Offsite Power See Item 9. for all Loss-of-Offsite Power Surveillance Requirements.

Start Motor-Driven Pump and Turbine-Driven Pump

8. Automatic Switchover to l

Containment Sump

a. Automatic Actuation N.A.

N.A.

M(1)

M(1)l

~Q-1, 2, 3, 4 1

L ic and Actuation Re ays

=-

b. RWST Level Low-Low N.A.

R Q

Q(3).

N.A.

1, 2, 3,-.4 l

[

Coincident With s

Safety Injection See Item 1. above for all ' Safety Injection Surveillance Requirements.

1 T

w e

i- -w 2'e, w

s

l

.M TABLE 4.3-2 (Continued)

ENGINEERED SAFETY F EATU.tES A:TJATION SYS"EM INSTRUMENTATION

^

f SJ (VEI _LAN: E:LEQUI TMEN"5 8

TRIP c

ANALOG ACTUATING MODES 5

CHANNEL DEVICE MASTER SLAVE FOR WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE ~

FUN:TIONAL ljNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEEI IESI IS REQUIREDJ:

~

9.. Loss of ?ower (Start)

Emergency Feedwater)

a. 4.16 kV Bus E5 and N.A.

R N.A.

M N.A.

N.A.

1, 2, 3, 4 E6 Loss of Voltage,

b. 4.16 kV Bus E5 and N.A.

R N.A.

M N.A.

N.A.

1, 2, 3, 4 E6 Degraded Voltage Coincident With Safety Injection See Item 1. above for all Safety Injection Surveillance Requirements

,,s

10. Engineered Safety

~ '

y Features Actuation g

System Interlocks

a. Pressurizer N.A.

R Q

N.A.

1, 2, 3

'l Pressure, P-ll

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

N.A.

, M.A.

N.A.

R N.A..

N.A.

1, 2, - 3 3

c. Steam Generator S

R Q

-N.A.

M(1)-

Q 1, 2, 3 l

Water Level, P-14 TABLE NOTATION h

g (1) Each train shall be-tested at least every 62 days on a STAGGERED TEST BASIS.

(2) A DIGITAL-CHANNEL OPERATIONAL TEST will be performed on this instrumentation.

(3) Setpoint verification is not applicable.

s M

j

=..

w1,,

INSTRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RADIATION MONITORING FOR PLANT OPERATIONS LIMITING CONDITION FOR OPERATION 3.3.3.1 The radiation monitoring instrumentation channels for plant operations shown in Table 3.3-6 shall be OPERABLE with their Alare/ Trip Setpoints within the specified limits.

APPLICABILITY: As shown in Table 3.3-6.

ACTION:

1 a.

With a radiation monitoring channel Alarm / Trip Setpoint for plant operations exceeding the value shown in Table 3.3-6, adjust the Setpoint to within the limit within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels for plant operations inoperable, take the ACTION shewn in Table 3.3-6.-

c.

The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REOUIREMENTS 4.3.3.1 Each radiation monitoring instrumentation channel for plant operations shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and DIGITAL CHANNEL OPERATIONAL TEST for the MODES and at the frequencies shown in Table 4.3-3.

SEABROOK - UNIT 1 3/4 3-36

3/4.3' INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM and ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION The OPERABILITY of the Reactor Trip System and the Engineered Safety ~

Features Actuation System instrumentation and interlocks ensures that: (1) the associated ACTION and/or Reactor trip will be initiated when the parameter monitored by each channel or combination thereof reaches its Setpoint (2) the specified coincidence logic is maintained, (3) sufficient redundancy is main-tained to permit a channel to be out-of-service for testing or maintenance, and-(4) sufficient system functional capability is available from diverse parameters.-

The OPERA 8ILITY of these systems is required to provide the overall reliability, redundancy, 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 safety analyses. The Surveillance Requirements speci-fled for these systems ensure that the overall system functional capability is maintained comparable to the original design standards. The periodic surveil-lance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

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

-veillance Frequencies and Out of Service Times for the Reactor Protection In-strumentation 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 NRC Safety Evaluation Reports for WCAP-10271. and its supplements and revisions were provided on February 21, 1985, February 22, 1989 and April 30, 1990.

The Engineered Safety Features Actuation System Instrumentation Trip Setpoints specified in Table 3.3-4 are the nominal values at which the bistables are set for each functional unit. A Setpoint is considered to be adjusted consistent with the nominal value when the "as measured" Setpoint is within the band allowed for calibration accuracy.

To accommodate the instrument drift assumed to occur between operational-tests and the' accuracy to which Setpoints can be measured and calibrated, Allowable Values for the Setpoints have been specified in Table 3.3-4.

Opera-tion with Setpoints less conservative than the Trip Setpoint but within the Allowable Value is acceptable since an allowance has been made in the safety analysis to accommodate this error. An optional provision has been included for determining the OPERABILITY of a channel when its Trip Setpoint is found to exceed the Allowable.Value. The methodology of this option utilizes the-"as measured" deviation from the specified calibration point for rack and sensor components'in conjunction with a statistical combination of the other SEABROOK - UNIT 1 B 3/4 3-1 Amendment No. 36

INSTRUMENTATION' BASES 3/4.3.1-and 3/4.3.2 REACTOR TRIP SYSTEM and ENGINEERED SAFETY FEATURES ACIUATION $YSTEM INSTRUMENTATION (Continued) uncertainties of the instrumentation to measure the process variable and the uncertainties in calibrating the instrumentation.

In' Equation-2.2-1, l_

Z + R S s TA,~the interactive effects of the errors in the rack and the sensor, and the "as measured" values of the errors are considered..Z, as specified in Table 3.3-4, in ppreent span, is the statistical summation of errors assumed in the analysis excluding those associated with the sensor and rack drift.and the accuracy of their measurement. TA or Total-Allowance is the differarce, in percent span; R or Rack Error is the "as measured" deviation, in the percent span, for the affected channel from the specified Trip Setpoint.

S or Sensor Error is either the "as measured" deviation of the sensor from its calibration point or the value specified in Table 3.3-4, in percent span, from the analysis i.

a assumptions. Use of Equation 2.2-1 allows for a sensor drift factor, an l

increased rack drift factor, and provides a threshold value for REPORTABLE EVENTS.

The methodology to derive the Trip Setpoints is based upon combining all of the uncertainties in the channels.

Inherent to the determination of the Trip Setpoitits are the magnitudes of these channel. uncertainties.

Sensor and rack instrumentation utilized in these channels are expected to be capable of operating within the allowances of these uncertainty magnitudes.. Rack drift in excess of the Allowable Value exhibits the behavior that the rack has not met i

its allowance.

Being that there is a small statistical chance that this will happen, an infrequent excessive drift is expected.

Rack or sensor drift, in excess of the allowance that is more than occasional, may be indicative of more i

serious problems and should warrant further investigation.

The measurement of response time at the specified frequencies provides assurance that the Reactor trip and the Engineered Safety. Features actuation associated with each channel is completed within the time limit assumed in the safety 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 j

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 time.

The Engineered Safety Features Actuation System senses selected plant parameters and determines whether or not predetermined limits are being exceeded.

If they are, the signals are combined into logic matrices sensitive to combinations indicative of various accidents, events, and transients. Once t

the required logic combination is completed, the system sends' actuation signals to those Engineered Safety Features components whose aggregate function best serves the requirements of the condition. As an example, the following actions may be initiated by the Engineered Safety Features Actuation System to mitigate the consequences of a steam line break or loss-of-coolant accident:

(1) Safety SEABROOK - UNIT 1 B 3/4 3-2 Amendment No. 34 3

,,

ML20082H949

Text

Attachment:

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