Text

Amend 13 to License NPF-87,revising TS & Associated Bases to Increase Surveillance Test Intervals & Allowed Outage Times for Analog Channels of Reactor Trip Sys & Engineered Safety Features Actuation Sys
	ML20127H473
Person / Time
Site:	Comanche Peak
Issue date:	01/12/1993
From:	Black S; Office of Nuclear Reactor Regulation
To:	;
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	NUDOCS 9301220340
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UNITED STATES 8 'i I

NUCLEAR REGULATORY COMMISSION w

e

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g xi w4 sm NG TON, D. C. 20555

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TEXAS U11LITIES ELECTRIC COMPANY. ET AL.*

.(QiANC}JE PEAK STEAM ELECTRIC STATION. UNIT 1

~

DOCKET NO. 50-445 AMENDMENT TO FACILITY OPERATING tJ EN_SE Amendment No. 13 License No. NPF-87 1.

The Nuclear Regulatory Comission (the Comruission) has found that:

A.

The application for amendment by Texas Utilities Electric Company (TV-Electric) acting for itself and as agent for Texas Municipal Power Agen;y (licensees) N;d April 26, 1991, and as supplemented by letters of May 4,19f 2 ac4 October 15, 1992, complies with the standards and reqvirumints of the Atomic Energy Act af 1954, as i

amended (the Act),.nd the Comission's rules and regulations set i

forth in 10 CFR Cbs te I; 8.

The facility wl11 operatt. in conformity with the application, as amended, the prtvisicas of the Act, and the rules and regulations of the Commission; C.

There is reasnnable assurance:

(i) that th'e 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:

D.

The issuance of this license amendment will not be inimical to the comon 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.

The current owners of the Comanche Peak Steam Electric Station are: Texas Utilities Electric Company and Texas Municipal Power Agency. Transfer of ownership from Texas Municipal Power Agency to Texas Utilities Electric Company was previously authorized by Amendment No. 9 to Construction Permit CPPR-126 on August 25, 1988 to take place in 10 installments as set forth-in the Agreement attached to the application for Amendment dated March 4,1988.

At the completion thereof, Texas Municipal Power Agency will no longer retain any ownership interest.

9301220340 930112 PDR ADOCK 05000445 P

PDR

e

.2-2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to thir, license amendment and ParagrapF 2.C.(2) of Facility Operating License No. NPF-87 is hereby amended to read as follows:

2.

Technical Soecifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 13, and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated in the license. The licensee shall operate the iacility in accordance with the Technical Specifications and the EnJironmental Protection Plan.

3.

The license amendment is effective as of its date of issuance and to be implemented within 30 days of issuance.

FOR THE NUCLEAR REGULATORY C0ffilSS10N tb M

Suzanne C. Black, Director Project Directorate IV-2 Division of Reactor Projects III/IV/V Office of Nuclear Ret ctor Regulation Attachmerit:

Changes to the Technical Specifications Date of Issuance:

January 12, 1993

7-ATTACHMENT-TO LICENSE AMENDME.NT NO. -13 FACILITY OPERATING ifCENSE NO. NPF-87 DOCKET N0i 50-445 Revise Appendix A Technical Specifications by removing the pages. identified below and inserting the enclosed pages. The revised pages are identified by amendment number and contain marginal lines indicating the area of change.

The corresponding overleaf pages are also provided to maintain document completeness.

REMOVE INSERT 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 3/4 3-5 3/4 3-7 3/4 3-7 3/4 3-15 3/4 3-15 3/4 3-16 3/4 3-16 3/4 3-18 3/4 3-18 3/4 3-19 3/4 3-19 3/4 3-20 3/a 3-20 3/4 3-21 3

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 3-35 3/4 3-35 B 3/4 3-1 B 3/4 3-1 B 3/4 3-2 B 3/4 3-2 1

9

h 3/4.3 -'INsTRilMENTATION >

~

c

. 3/4.3.1 REACTOR TRIP. SYSTEM INSTRUMENTATION'-

- LIMITING CONDITION FOR OPERATION 3.3.1 As a minimum, the Reactor Trip System instrumentation'channelsLand -

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 REQUIREMENTS 4.3.1.1. Eich 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 Requiracants specified in:

Table 4.3-1.

4.3.3.2 The REACTOR TRIP SYSTEM RESPONSE TIME of each Reactor trip function sha111be demonstrated to be within its limit.at-1 cast 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 functionLsuch that-all channels are tested at least once every N times 18 monthr where N<is-.the total: number. -

of redundant channels _in a specific. Reactor. trip function as~shown11n;the

" Total No. of Channels" column'of_ Table 3.3-11 1 -

4 1

i L

COMANCHE PEAK _- UNIT 1 3/4 3 "

7 us Y(OV f

+

-,w+

TABLE 3.3-1 n

REACTOR TRIP SYSTEM INSTRUMENTATION 9

m MINIMUM g

TOTAL NO.

CHANNELS CHANNELS APPLICABLE

-g FUNCTIONAL < UNIT Of CHANNELS TO TRIP OPERABLE MODES ACTION-

[

1.

Manual Reactor Trip 2

1 2

1, 2 1

h 2

1

'2 3,4,S 9

a a

a 2.

Power. Range, Neutron Flux a.

High Setpoint 4

2 3

1, 2 2

c b.'

Low Setpoint 4

2 3

1,2 2

3.

Power Range, Neutron Flux 4

2 3

1, 2 2

High Positive Rate 4.

Power Range, Neutron Flux, 4

2 3

1, 2 2-High Negative Rate c

5.

Intermediate Range, Neutron Flux 2

1 2

I,2 3

6.

Source Range, Neutron Flux a.

Reactor Trip and Indication b-1)

'Startup-2 1

2 2

4 2)

' Shutdown 2

1 2

3,4,5 5.1 h

b.

Boron Dilution Flux Doubling * -

2 1

2 3

,4, 5

5.1, 5.2 g

7.

Overtemperature N-16 4.

2 3

1, 2 12 8.

Overpower N-16 4

2 3

1, 2 12 A

9.

Pressurizer Pressure--Low 4

2 3,

l 6

l d

5

~

10.

Pressurizer Pressure--High 4

2 l3 1, 2 6

5

~

' Boron Dilution Flux Doubling requirements become effective for Unit I six months O

'after criticality for Cycle 3.

g e-

-e

TABLE 3.3-1 (Continued) o 5

REACTOR TRIP SYSTEM INSTRUMENTATION z9 MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE OF CHANNELS TO TRIP-OPERABLE MODES ACTION m

E FUNCTIONAL UNIT d

i 11.

Pressurizer Water Level--High 3

2 2

I 6'

=

I 6

12.

Reactor Coolant Flow--Low a.

Single Loop ~

3/ loop 2/ loop in 2/ loop I

any 1oop b.

Two Loops 3/ loop 2/ loop in 2/ loop 19 6

any two loops w

13.

Steam Generator Water 4/stm. gen.

2/stm. gen.

3/stm. gen.

1, 2 6*

~l in any stm.

1 Level -Low-Low gen.

d Y

14.

Undervoltage--Reactor' Coolant 4-1/ bus-2 3

I 6

Pumps d

15.

Underfrequency--Reactor Coolant 4-1/ bus 2

3' I

6 Pumps-

'l 16.

Turbine Trip 2

.2 13 6

a.

Low Fluid Oil Pressure 3

b.

Turbine Stop Valve Closure 4

-4 4

l' 10 2i -

1 2-

' 1, 2 -

13 l

i.

2 g. 17.

Safety Injection Input from ESFAS

l g

A E.

TABLE 3.3-1 (Continued) n

- o

. h' REACTOR' TRIP SYSTEM INSTRUMENTATION g

a MINIMUM A

TOTAL N0.

CHANNELS CHANNELS APPLICABLE R

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION-h 18.

Reactor Trip System Interlocks b

5 a.

Intermediate Range 2

1 2

2 7

Neutron Flux, P-6 i

e b.

Low Power Reactor Trips Block, P-7 1)

P-10 Irput 4

2 3

1,2 7

2)-

P-13 Input 2

1-2 1

7 c.

Power Range Neutron 4

2 3

1 7

Flux..-P-8 m5 i

d.

Power Range Neutron 4

2 3

1 7

w A

Flux, P-9 e.

Power Range Neutron 4

2 3

1, 2 7

Flux, P-10 19.

Reactor Trip Breakers 2

1 2

1, 2 8, 11-a E

a 2

1 2

3,4,5 9

.. l' 20.

Automatic Trip and Interlock 2

1 2

1, 2 13 a

a a

Logic 2

1 L2 3,4,5 9

b

=

et i

C.

e 4 i g

A b

=

4 TABLE 3.3-1 (Continued)

TABLE NOTATIONS

'Only if the reactor trip breakers happen to be in the closed position and the Control Rod Drive System is capable of rod withdrawal.

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

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

dAbove the P-7 (At Power) Setpoint.

' Deleted.

'Above the P-8 (3-loop flow permissive) Setpoint.

Above the P-7 and below the P-8 Setpoints.

S hThe boron dilution flux doubling signals may be blocked during reactor startup.*

'Above the P-9 (Reactor trip on Turbine trip Interlock) Setpoint.

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 STANDBY 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'0PERAT10N 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 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, i

the QUADRANT POWER TILT RATIO is monitored:at least once per 12 hoLrs per Specification 4.2.4.2.

~

IBoron Dilution Flux Doubling requirements become effective for Unit I six months after criticality for Cycle 3.

COMANCHE PEAK - UNIT 1 3/4 3-5 Amendment No. 40,13

[

TABLE 3;3-1 (Continued)

ACTION STATEMENTS (Continued)

ACTION 3

- With the number of channels OPERABLE one less than the Minimum 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, b.

Above the P-6 (Inte mediate Range Neutron Flux Interlock)

Setpoint but below 10% of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 10% of RATED THERMAL POWER.

ACTION 4

- With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, suspend all operations involving positive reactivity changes.

ACTION 5.1 - With the number of OriRABLE 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 within the next hour open the reactor trip breakers and suspend all operations involving positive reactivity changes. With no channels OPERABLE complete the above actions within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

ACTION 5.2*- With the number of OPERABLE channels one less than the Minimum Chinnels 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 within the next. hour-verify either valve 1CS-8455 or valves 1CS-8560, FCV-IllB,10S-8439, 105-8441, and ICS-8453 are closed and secured in position, and verify this position at least onca per 14 days thereafter.- With no channels OPERABLE, complete the above actions within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and verify the positions of the above valves at least once per 14 days 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:

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 other channels per Specification 4.3.1.1.

ACTION 7

- With less than the Minimum 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.

Moron Dilution FTuTDoubling requirements become effective for Unit 1 six months after criticality for "vcle 3.

COMANCHE PEAK - UNIT 1 3/4 3-6 Amendment No. 10

t TABLE 3.3-1 ((pntinued)

ACTION STATEMENTS (Continued)

ACTION 8 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, be in at least 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 or maintenance, provided the other channel is OPERABLE.

With the number of OPERABLE channels one less than the Minimum ACTION 9 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 10 - With the number of OPERABLE channels less than the Total Number of Channels, operation may continue provided the inoperable channels are placed in the tripped conditin", within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 11 - 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 apply ACTION 8.

The breaker shall not be bypassed while one of the diverse trip features is inoperable except for the time required for performing maintenance to restore the breaker to OPERABLE-status, during which time ACTION 8 applies.

ACTION 12 - 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 per Specifications 4.3.1.1 or 4.2.5.4.

ACTION 13 - 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 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 OPERABLE.

i l

l l

COMANCHE PEAK - UNIT 1 3/4 3-7 Amendment No.13 l-

.n

.y-TABLE 4.3-1 z

1

~

g REAC10R TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS

g TRIP.

. ANALOG ACTUATING MODES FOR CHANNEL DEVICE WHICH c.

CHANNEL-CHANNEL OPERATIONAL OPERATIONAL

. ACTUATION.

SURVEILLANCE /

l g

FUNCTIONAL' UNIT CHECK CALIBRATION TEST:

- TEST LOGIC TEST-IS REQUIRED I

H 1.

Manual Reactor Trip-:

N.A.

N. A.

R(14)

N.A.

.1, 2, 3, 4

'a a

Sa 2.

Power Range, Neutron Flux a.

High Setpoint S

.D(2,4),

Q

. N. A.-

N.A.

1, 2

_M(3,.4)..

Q(4,:L 6),

R(4, 5) b.

Low Setpoint S-R(4).

S/U(1)

N. A.'

N.A.

-'1, 2 I

c

ws

~

3.

Power Range.. Neutron Flux, N.A.

R(4):

Q N. A.

N.A.

. 1, L 2 High' Positive Rate-w-

co 4.

- Power Range, Neutron Flux, N.A.

R(4): .

Q N. A. -

N.A.

1, 2 High Negative Rate i

' \\

5.

Intermediate' Range, S

LR(4,5)'

S/U(1)-

N.A.

I,'2"

~

c

~ Neutron Flux

(

' Source Range, Neutron Flux:S:

R(4, L13) 5/U(1),Q(9)

R(12)*

N.A.

- 2, 3. 4, 5

6; b

i

.7.

.0vertemperature N-16L

.. S

.:., 0(2,.4 )

'.Q' N.A.

N.A.

1. 2-

.N(3.)4)_

1 Q(4,6):

p

R(4,5),

R.

i 8.

. Overpower N-16 1S; D(2,.4)"

-Q:

-N.A.

N.A.

- 1,-2 i

~

R(4,l.5) '

l-z d

P1 9.

PressurizerPressure--LowL;S

-.R ;;

Q(8).

N. A.

M.A.

1

' E$

102 Pressurizer Pressure--High:S

R;

!.Q '

.N.A.'

' N. A.-

1,.2-J*

"* Boron D'ilution: Flux-Doubling requirements become' effective for Unit -1 six months..-

'h l

.after criticality?for Cycle 13.

.. t g) 9 w-

,:A-,,y

(

g-

/r 61 p.i't WW

il k'

'#T'IS WmTdr

E3

-TABLE 3.3-2 ENGINEERED SAFETY FEATURES tCTUATION SYSTEM INSTRUMENTATION 9

m MINIMUM

??

TOTAL NO.

CHANNELS CHAMNELS APPLICABLE-3; FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION C

E5 1.

Safety Injection (ECCS,

-4 Reactor Trip, Feedwater Isolation, Control Room Emergency Recirculation, Emergency Diesel Generator Operation, Containmer.t Vent Isolation, Station Service Water,-Phase A Isolation, Auxiliary Feed-R water-Motor Driven Pump, Turbine Trip, Component Y

Cooling Water, Essential t

Ventilation Systems, and Containment Spray Pump.

a.

Manual Initiation

'2 1

2 1,2,3,4 16 b.

Automatic Actuation 2

l' 2

1,2,3,4 26 l

Logic and Actuation p

Relays El c.

Containment 3

2 2

1,2,3 17 G

Pressure--High-1 G-a d.

Pressurizer 4

2 3

1,2,3 37

=-

Pressure--Low a

Steam Line' Pressure--Low 3/ steam line' 2/ steam line.

2/ steam line 1,2,3 17 e.

in any steam line-

TABLE 3.3-2 (Continued)

S SE ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 9

m

'?,

MINIMUM N'

TOIAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION E

2.

Containment Spray Manual Initiation 2 pair 1 pair 2 pair 1,2,3,4 16 a.

operated simultaneously b.

Aistomatic Actuation 2

1 2

1,2,3,4 26 Logic and Actuation Relays c.

Containment Pressure--

4 2

3 1,2,3 14 y

High-3 T

3.

Containment Isolation u

a.

Phase "A" Isolation 1)

Manual Initiation 2

1 2

1, 2, 3, 4 16 2)

Automatic Actuation 2

1 2

1,2,3,4 26 Logic and Actuation Relays 3)

Safety Injection See Item 1. above for all Safety Injection initiating functions and requirements.

b.

Phase "B" Isolation 1)

Manual Initiation See Item 2.a above.

Phase "B" isola-1,2,3.4

-16

. tion is manually initiated when containment spray functicn is manually initiated.

2)

Automatic Actuation

'2 1

2 1,2,3,4 26 l

E Logic and Actuation

~

Relays U

3)

Containment 4

2 3

1,2,3 14 Pressure--High-3

.l I

~

- ?Q 4

TABLE 3.3-2 (Continued) 8 h-ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION E

m MINIMUM

~ E TOTAL NO.

CHANNELS CHANNELS APPLICABLE m

7 FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION E

Containment Vent U

Isolation 1)

Manual Initiation See Item 2.a and 3.a.1 above.

1,2,3,4 15 Containment vent isolation is manually initiated when Phase "A" isolation function or containment spray function is manually initiated.

2)

Automatic Actuation 2

1 2

1,2,3,4 15 logic and Actuation

,g Relays 3)

Safety Injection' See Item 1. above for.all Safety Injection initiating functions and-requirements.

4.

Steam Line Isolation a.

Manual Initiation c

c

1) Individual Steam 1/ steam line 1/ steam line 1/ operating 1,2,3 21 steam line Line-i c

C

2) System 2

1 2

1, 2, 3 20 C

C b.

Automatic Actuation 2

1 2-1, 2, 3 19

. Logic and Actuation-Relays c

c c.

Containment Pressure--

3 2

2 1, 2, 3 77

- High-2 --

g TABLE 3.3-2 (Continued) b ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 2

m v

m MINIMUM M

TOTAL NO.

CHANNELS CHANNELS APPLICABLE i

FUNCTIONAL UNIT OF CHANNELS TO TRIP (DERABLE MODES ACTION E

4.

Steam Line Isolation (Continued)

]

d.

Steam Line Pressure--Low 3/ steam line 2/ steam line 2/ steam line 1, 2, 3,c 77 C

a in any steam line b

e.

Steam Line Pressure -

3/ steam line 2/ steam line 2/ steam line 3,c 17 l

Negative Rate--High in any steam line w

5.

Turbine Trip and 1

Feedwater Isolation Y

a.

Automatic Actuation 2

1 2

1, 2 22 M

Logic and Actuation Relays b.

Steam Generator 3/stm. gr.n."

2/stm. gen.

1, 2 17 Water Level--

in any stn.

l High-High gen.

c.

$afety Injection See Item 1. above for all Safety Injection initiating functions and requirements.

6.

Auxiliary Feedwater a.

Automatic Actuation Logic 2

1 2

1,2,3 19

{

and Actuation Relays i

b.

Stm. Gen. Water Level--

T$

Low-Low

1) Start Motor-4/stm. gen.

2/stm. gen.

3/stm. gen.

1,2,3 17 5

Driven Pumps in any oper-in each ating stm. gen.

operating stm. gen.

w

s

TABLE 3.3-2 (Continued) 8 h

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE E

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION M

6.

Auxiliary Feedwater (Continued) d Z

2) Start Turbine-4/stm. gen.

2/stm. gen.

3/stm. gen.

1, 2, 3 17 c-Driven Pump in any in each 2 operating operating g

stm. gen.

stn. gen.

j See Item 1. above for all Safety Injection initiating functions and c.

Safety Injection Start Motor-Driven Pumps requirements.

d.

Loss-of-Offsite Power 1/ train 1/ train 1/ train 1, 2, 3 16 Start Motor-Driven w2 Pumps and Turbine-Driven Pump Trip of All Main 2/AFW pump 2/AFW pump 1/AFW pump 1, 2 '

23 w

M e.

Feedwater Pumps Start Motor-Driven Pumps 7.

Automatic Initiation of ECCS Switchover to Containment

}

Sump Automatic Actuation 2-1 2

1,2,3,4 26 l

8 Po a.

A Logic and Actuation Relays g

1 1

g TABLE 3.3-2 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM A-TOTAL NO.

CHANNELS CHANNELS APPLICABLE R

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION e

7.

Automatic Initiation of ECCS..

i5 Switchover to' Containment

]

Sump (Continued) b.

RWST Level--Low-Low 4

2 3

1,2,3,4 17 l

Coincident With: Safety See Item 1. above for all Safety Injection initiating functions Injection and requirements.

8.

Loss of Power (6.9 kV & 480 V Safeguards-System Undervoltage)

I I I I a.

6.9 kV Preferred Offsite 2/ bus 2/ bus 1/ bus I,2,3,4 23 Source Undervoltage w

5 b.

6.9 kV Alternate Offsite 2/ bus 2/ bus 1/ bus 1, 2, 3, 4 23 Source Undervoltage c.

6.9 kV Bus Undervoltage 2/ bus 2/ bus 1/ bus 1, 2, 3, 4 23 d.

6.9 kV Degraded Voltage 2/ bus 2/ bus 1/ bus 1, 2, 3, 4 23 e.

480 V Degraded Voltage 2/ bus 2/ bus

'1/ bus 1, 2, 3, 4 23-1

.f.

480 V Low Grid 2/ bus 2/ bus 1/ bus 1,2,3,4 23 Undervoltage 9.

Control Room Emergency y

Recirculation a.

Manual Initiation 2

1 2

All 24 O

o O

h

.A, TABLE 3.3-2 (Continued) n ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 9

MINIMUM rn TOTAL NO.

CHANNELS CHANNELS APPLICABLE

gy FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION b.

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

[5 requirements

~-

10.

Engineered Safety Features Actuation System Interlocks a.

Pressurizer Pressure, 3

2 2

1,2,3 18 P-11 b.

Reactor Trip, P-4 2

2 2

1,2,3 20 y

11.

Solid State Safeguards Sequencer (5555) w a.

Safety Injection 1/ train 1/ train 1/ train 1,2,3,4 26 Sequence b.

Blackout Sequence 1/ train 1/ train 1/ train 1, 2, 3, 4 25 a

5 a

E

Y 4

TABLE 3.3-2 (Continued)

TABLE NOTATIONS

Trip function may be blocked in this MODE below the P-ll (Pressurizer Pressure Interlock) Setpoint.

Drip function automatically blocked above P-ll and may be unblocked below P-ll by blocking the Safety injection on. low steam line pressure.

'Not applicable if each affected main steam isolation valve and its associated upstream drain pot isolation valve per steam line is closed.

ihe provisions of Specification 4.0.4 are not applicable for entry into d

MODE 3.

'The channel which provides a steam generator water level control signal (if one of three specific trip channels is selected to provide input into steam generator water level control) must be placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and maintained in the tripped condition with the exception that the channel may be taken out of the tripped condition for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to allow testing of redundant channels.

'Not applicable if Preferred Offsite Source Breaker is open.

ACTION STATEMENTS ACTION 12 - Deleted.

ACTION 13 - Deleted.

ACTION 14 - With the number of OPERABLE channel 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 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.

ACTION 15 - With less than the Minimum Channels OPERABLE requirement, operation may continue provided the containment pressure relief valves are closed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and maintained closed.

ACTION 16 - With the number of OPERABLE channels one less than the Minimum Channals 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 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 .

COMANCHE PEAK - UNIT 1 3/4 3-22 Amendment No. 13

- _ _. _.~ _ m

-y

'l a

..g

_ABLE 3.3-2 fContinued)

T w

ACTION STATEMENTS (Co'ntinued)

ACTION 17 - With the number of OPERABLE channels one less than the Total' Number of Channels, operation may proceed provided the following

-l conditions are satisfied.-

The inoperable channel is placed in the tripped condition within-6 hours, and b.

The Minimum Channels OPERABLE-requirement is met;- however, 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 of other channels per Specification 4.3.2.1.

ACTION 18 - With less than the Minimum Number of C5annels 0 PEP.ABLE,-within-li 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.-

ACTION 19 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channelz 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 HOT SHUTDOWN within the:following 6_.

hours; 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 20 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE.

status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ~or be-in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT--SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .;

ACTION 21 - With the number of OPERABLE 1 channels one less than' the' Total.

Number of Channels, restore the inoperable 1 channel to'0PERABLE:

status-within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare-thel associated; valve inoperable and'take the ACTION required.by Specification 13.7.1.5.

ACTION 22 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the' inoperablec 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 1 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 OPERABLE.

ACTION 23 - 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:

1 e

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.

1:

1

-l COMANCHE PEAK - UNIT 1 3/4 3-23 Amendment No.13 j

.\\

t

r TABLE 3.3-2 (Continued)

ACTION STATEMENTS (Continued.1 ACTION 24 - 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 initiate and maintain operation of the Control Room Emergency Recirculation System.

ACTION 25 - With the number of OPERABLE channels on one or more trains less than the Minimum Ch'nnels OPERABLE requirement, declare the diesel generator (s) assceiated with the affected train (s) inoperable and apply the appropriate ACTION for Specification 3.8.1.1.

ACTION 26 - 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 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 surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

COMANCHE PEAK - UNIT 1 3/4 3-24 Amendment No. 13

.q 3y QV r

4 l

TABLE'4.~3-2 (Continued).

,.o5

- ENGINEERED SAFETY FEATURES ACTUATION SYSTEN INSTRUMENTATION c

h SURVEILLANCE REQUIREMENTS-

t..

m

' TRIP

g ANALOG

ACTUATING POSESu g

CHANNEL DEVICE MASTER: SLAVE FOR WHICH' CHANNEL' CHANNEL. CHANNEL

-OPERATIONAL' OPERATIONAL -ACTUATION-RELAY RELAYL SURVEILLANCEE FUNCTIONAL UNIT CHECK

~ CALIBRATION' TEST TEST LOGIC TEST TEST

~ TEST' ' IS' REQUIRED

.e

[

7. Automatic Initiation of-ECCS Switchover'to' Containment.

Sump (Continued)

b. RWST. Level-Low-Low

5

SR

'Q N.A.

N.A.

N. A.

N.A 1,2,3,4' Coincident With' SafetyInjection..

See Item?l. above for all Safety Injection Surveillance Requirements.

w s

[

8. Loss of Power (6.9 kV &-

J,

'480 V Safeguards'..

System Undervoltage) u' a.

6.9 kV Preferred Offsite' Source Undervoltage N.A.

.R.

' N.~ A.

(3,2)

N.A.

1 ; 2, 3, 4..

b.

6.9 kV Alternate OffsiteL

.N.A.

(3,2)-

. N.' A.

N.A.

1, 2, 3,.4 Source Undervol.tage-N.A.

.R.

c.

6.9 kV Bu's Under"-

voltage'

.N.A.

R lN.A.

-(3,2)-

' N. A.~

N. A.'

NJA.

' 1, 2,' 3,,4

,a d.

6 9 kV Degraded i

Voltage

'N.A.

R' N. A.'

-(3,2)

N. A.-

N.A.

' ti. A.

1,)2,3,4:

.480 V. Degraded-e.

.g Voltage l N.A._

R-

N. A.'

l(3,2).

- N. A.:.

MN.A.

N.- A.

1, 2,;3, 4

-f.

480 V Low Grid ~

Undervoltage:-

.N.A.

.R.

N.A.

l(3,J2)

NiA..

N. A.1 1 N. A..-

.1,2,3,4

^

,_L,,

TABLE 4.3-2 (Continued)

,o 3E ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS TRIP m

92 ANALOG ACTUATING MODES CHANNEL DEVICE' MASTER SLAVE FOR WHICH E

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY' SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TFST LOGIC TEST TEST TEST 15 REQUIRED s

9.

Control Room Emergency Recirculation

-a.

Manual Initiation N.A.

N.A.

R N.A.

N.A.

All b.

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

10. -Engineered Safety u,

3s Features Actuation System Interlocks to I

a.

Pressurizer N.A.

R Q

N.A.

1,2,3 Pressure, P-11 b.

Reactor Trip, P-4 N. A.

N.A.

R N.A.

N. A.

N.A.

1, ;2, 3 11.

Solid State Safeguards.

Sequencer (5555) t a.

Safety Injection N.A.

R-N.A.

M(1,3,4)

N.A.

1, 2, 3, 4 Sequence b.

Blackout Sequence N.A.

R N. A.

M(1,3,4)

N.A.

1, 2, 3, 4' I

'I r

iO s+

l

's 3/4.3.hGlfM101 TAT 10N pSrS 3113.1 And 3]L3.2 RE& LOR 1RLP_. SYSTEM AND ENGillEIRLD SAFE 1Y FEATURES AClVATION SYSTEM INSlRUMENTATION 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 and sufficient redundancy is mintained 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 instrumentation, and (3) sufficient system functional capability is available from diverse parameters.

The OPERADILITY of these systems is recuired to provide the overall-reliability, redundancy, and diversity assumet available in the facility design for the protection end mitigation of accident and transient conditions.

The integrated operation of each of these systems is consistent with the assumptions esed in the safety analyses.

The Surveillance Requirements specified f or 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 accorriance with WCAP-10271, " Evaluation of Surveillance frequencies and Out of Service Times for the Reactor Frotection lastrumentation System", WCAP-10271 Supplement 2 " Evaluation of Surveillance Frequencies and Out of Service Times for the Engineered Safety Features Actuation System" and supplements to these reports as approved by the NRC and oocumented in tne SER (letters to the Westinghouse Owners Group (WOG) dated February 21, 1985, February 22, 1989, ana April 30, 1990).

The Engineered Safety features Actuation System Instrumentation Trip Setpoints specified in Table 3.3-3 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 Set 30ints can be measured and calibrated. Allowable Values for the Setpoints lave been specified in Table 3.3-3.

Operation 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 acccmmodate 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. uncertainties of the instrumentation to measure the process variable and the uncertainties in calibrating the instrumentation.

In Equation 2.2-1.

Z + R + S 3; 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 3.3-3, in percent span, is the statistical summation of errors assumed in the analysis excluding those COMANCHE PEAK - UNIT 1 P 3/4 3-1 Amendment No. 13

5 1RSTRUMENTA110y DASES RLA.CJDR_lRIP_51SlEM AND ENGlNEERED SAFEIY FEAl@LLAG%11DR SYSTEM 11(kJRUMENT AT1Q!N_(Continued) e associated with the sensor and rack drift and the accuracy of their measurement.

TA or Total Allowance is the difference, in percent span, R or Rack Error is the "as measured" deviation, in the percent span, for the af fected channel from the specified Tri) Setpoint.

S or Sen:or Error is either the "as measured" deviation of tle sensor from its calibration point or the value specified in Table 3.3-3, in percent span, from the analysis assumptions.

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

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

The methodology to derive the Trip 5etpoints is based upon combining all of the uncertainties in the channels.

Inherent to the determination of the Tria Setpoints are the magnitudes of there channel uncertainties.

Sensor and rac( instrumentation utilized in these channels are expected to be capable of operating within the allowances of these uncertainty. magnitudes.

Rack I

drift in excess of the Allowable Value exhibits the behavior that the rack has not met its allowence.

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 serious problems and should warrant further investigation.

The measurement of response time specified in the Technical Requirements Manual 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 defined.

Sensor response time verification may be demonstrated by either: -(l) 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 the required logic combination is campleted, the system sends actuation-signals to those Engineered Safety Fcatures 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) ECCS pumps start and automatic valves position, (2) Reactor trip, (3) feedwater isolation, (4) startup of the emergency diesel generators, (5) containment spray pumps start and automatic valves position, (6) contain-ment isolation, (7) steam line isolation,. (8) turbine trip, (9) auxiliary feedwater pumps start and automatir valves position, (10) station service water pumps start and automatic valves position, (11) Control Room Emergency Recirculation starts, and (12). essential ventilation systems (safety chilled water, electrical area fans, primary plant ventilation ESF exhaust fans, battery room exhaust fans, and UPS ventilation) start.

COMANCHE PEAK - UNIT 1 B 3/4 3-2 Amendment No. 13

.

ML20127H473

Text

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