Text

Amends 122 & 116 to Licenses NPF-35 & NPF-52,respectively, Changing TS to Allow for Longer Surveillance Test Intervals & AOTs
	ML20071J179
Person / Time
Site:	Catawba
Issue date:	07/19/1994
From:	Berkow H; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20071J182	List: ML20071J179; ML20071J185;
References
	NUDOCS 9407270218
	Download: ML20071J179 (33)
	v • d • e

pn M%q'o l

1

[\\ i*(

k UNITED STATES 5i NUCLEAR REGULATORY COMMISSION v,/

WASHINGTON, D.C. 2055%O001 DUKE POWER COMPANY NORTH CAROLINA ELECTRIC MEMBERSHIP CORPORATION SALUDA RIVER ELECTRIC COOPERATIVE. INC.

DOCKET NO. 50-413 CATAWBA NUCLEAR STATION. UNIT 1 AMEN 0 MENT TO FACILITY OPERATING LICENSE Amendment No. 122 License No. NPF-35 1.

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

A.

The application for amendment to the Catawba Nuclear Station, Unit 1 (the facility) Facility Operating License No. NPF-35 filed by the Duke Power Company, acting for itself, North Carolina Electric Membership Corporation and Saluda River Electric Cooperative, Inc. (licensees), dated January 25, 1993, as amended by letter dated May 12, 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 as 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.

9407270218 940719 PDR ADOCK 05000413 P

,n g.,9 j

I f 2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C.(2) of Facility Operating License No.

NPF-35 is hereby amended to read as follows:

Technical Soecifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 122, and the Environmental Protection Plan contained in Appendix B, botii of which are attached hereto, are hereby incorporated into this license.

Duke Power Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

This license amendment is effective as of its date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Wstkl=. N Herbert N. Berkow, Director Project Directorate 11-3 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation

Attachment:

Technical Specification Changes Date of Issuance:

July 19, 1994

I f

3 i) 3 UNITED STATES i g $' "J NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001

+...+

DUKE POWER COMPANY NORTH CAROLINA MUNICIPAL POWER AGENCY NO. 1 PIEDMONT MUNICIPAL POWER AGENCY DOCKET N0. 50-414 CATAWBA NUCLEAR STATION. UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 116 License No. NPF-52 1.

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

A.

The application for amendment to the Catawba Nuclear Station, Unit 2 (the facility) Facility Operating License No. NPF-52 filed by the Duke Power Company, acting for itself, North Carolina Municipal Power Agency No. I and Piedmont Municipal Power Agency (licensees), dated January 25, 1993, as amended by letter dated May 12, 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 as 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; l

C.

There is reasonable assurance (i) that the activities authorized i

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 tu the health and safety of the public; and j

E.

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

l

l I

e 2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C.(2) of Facility Operating License No.

NPF-52 is hereby amended to read as follows:

{

l Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 116, and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. Duke Power Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

This license amendment is effective as of its date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION

)(,Je v'. JAllhw he Herbert N. Berkow, Director j

Project Directorate II-3 1

Division of Reactor Projects - I/II 1

Office of Nuclear Reactor Regulation

Attachment:

Technical Specification Changes Date of Issuance:

July 19, 1994

)

4 s

ATTACHMENT TO LICENSE AMENDMENT NO.122 FACILITY OPERATING LICENSE N0. NPF-35 DOCKET NO. 50-413 ANQ i

TO LICENSE AMENDMENT NO. 116 FACILITY OPERATING LICENSE NO. NPF-52 DOCKET NO. 50-414 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages.

The revised pages are identified by Amendment number and contain vertical lines indicating the areas of change.

Remove Paaes Insert Paaes 3/4 3-1 3/4 3-1 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 3-6 3/4 3-6 l

3/4 3-9 3/4 3-9 3/4 3-10 3/4 1-10 3/4 3-11 3/4 3-11 i

3/4 3-12 3/4 3-12 l

3/4 3-14 3/4 3-14 3/4 3-18 3/4 3-18 3/4 3-19 3/4 3-19

'l 3/4 3-21 3/4 3-21 3/4 3-22 3/4 3-22 i

3/4 3-23 3/4 3-23 3/4 3-24 3/4 3-24 3/4 3-25 3/4 3-25 3/4 3-26 3/4 3-26 3/4 3-26a 3/4 3-26a 3/4 3-42 3/4 3-42 3/4 3-43 3/4 3-43 3/4.3-44 3/4 3-44 3/4 3-45 3/4 3-45 3/4 3-46 3/4 3-46 3/4 3-47 3/4 3-47 3/4 3-50 3/4 3-50 B 3/4 3-1 B 3/4 3-1

i e

3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.1 As a minimum, the Reactor Trip System instrumentation' channels and interlocks of Table 3.31 shall be OPERABLE with RESPONSE TIMES as shown in Table 3.3 2.

APPLICABILITY: As shown in Table 3.3 1.

ACTION:

As shown in Table 3.31.

SURVEILLANCE REQUIREMENTS 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 4.31.

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 I

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 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 3.31. The response time of RTDs associated with the Reactor Trip System shall be demonstrated to be within their limits at least once per 18 months.

I CATAWBA UNITS 1 & 2 3/4 3 1 Amendment No.122(ilnit 1)

Amendment No.116(Unit 2)

9y TABLE 3.3-1 6

7 REACTOR TRIP SYSTEM INSTURMENTATION E

MINIMUM Z

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL iwiT OF CHANNELS TO TRIP OFERABLE MODES ACTION 5

N 1.

Manual Reactor Trip 2

1 2

1. 2 1

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

1##. 2 2

3.

Power Range. Neutron Flux 4

2 3

1. 2 2

High Positive Rate l

4.

Intermediate Range. Neutron Flux 2

1 2

1##. 2 3

w A

5.

Source Range. Neutron Flux w

a.

Startup 2

1 2

2#

4 h

b.

Shutdown 2

1 2

3*,

4*, 5*

10 6.

Overtemperature aT Four Loop Operation 4

2 3

1. 2 6

7.

Overpower aT Four Loop Operation 4

2 3

1. 2 6

NEI gg 8.

Pressurizer Pressure-Low 4

2 3

1 6

I Y

a$

.&.F em CCdd ee vv l

i w--

TABLE 3.3-1 (Continued) n>

h REACTOR TRIP SYSTEM INSTRUMENTATION co MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE E

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

[

9.

Pressurizer Pressure-High 4

2 3

1, 2 6

l

[

10. Pressurizer Water Level-High 3

2 2

1 6

11. Reactor Coolant Flow-Low

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

6 any oper-each oper-ating loop ating loop

b. Two Loops (Above P-7 and 3/ loop 2/ loop in 2/ loop 1

6 below P-8) two oper-each oper-mg ating loops ating loop "a

12. Steam Generator Water 4/stm 2/stm gen 3/stm gen 1, 2 6

l Level--Low-Low gen in any each operating operating stm gen stm gen

((

13. Undervoltage-Reactor Coolant 4-1/ bus 2

3 1

6 gg Pumps (Above P-7)

R8 gg

14. Underfrequency-Reactor Coolant 4-1/ bus 2

3 1

6 Pumps (Above P-7)

CO[

15. Turbine Trip g

a. Stop Valve EH Pressure 4

2 3

1####

6

- Low gg

b. Turbine Stop Valve Closure 4

4 1

l####

11 oo EN

16. Safety Injection Input C

from ESF 2

1 2

1, 2 7

l

TABLE 3.3-1 (Continued)

Q REACTOR TRIP SYSTEM INSTURMENTATION h

MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FjjNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION i'i

17. Reactor Trip System Interlocks 5

a. Intervediate Range Neutron Flux. P-6 2

1 2

2#

8

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

wA Flux P-9 w

A

e. Power Range Neutron Flux. P-10 4

2 3

1 8

f. Power Range Neutron Flux. Not P-10 4

3 4

1. 2 8

9. Turbine Impulse Chamber gg Pressure. P-13 2

1 2

1 8

me kh

18. Reactor Trip Breakers 2

1 2

1. 2

9. 12 gg 2

1 2

3*. 4*. 5*

10 en

-gg

19. Automatic Trip and Interlock 2

1 2

1. 2 7

l Logic 2

1 2

3*. 4*. 5*

10 hh

20. Reactor Trip Bypass Breakers N.A.

N.A.

1.2.3*.4*.5*

13 EE dd on vv

f e

TABLE 3.3 1 (Continued)

TABLE NOTATIONS

0nly if the Reactor Trip System breakers happen to be in the closed position and the Control Rod Drive System is capable of rod withdrawal.

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.

1. 1. 1. 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 at least 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 OPERATION may proceed provided the following conditions are satisfieci:

a.

The inoperable channel is placed in the tripped condition within 6

hours, 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 surveil-lance 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 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s: 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.

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: or b.

Above the P 6 (Intermediate Range Neutron Flux Interlock) Setpoint but below 10t'of RATED THERMAL POWER restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 10% of RATED THERMAL POWER.

t CATAWBA UNITS 1 & 2 3/4 3 5 AmendmentNo.g(Unit 1) 1 Amendment No.

(Unit 2)

I

TABLE 3.3-1 (Continued)

TABLE NOTATIONS (Continued)

ACTION 4 -

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

ACTION 5 -

Delete 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 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.

ACTION 8 -

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

ACTION 9 -

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, provided the other channel is OPERABLE.

ACTION 10 -

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 11 -

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

l ACTION 12 -

With one of the diverse trip features (Undervoltage or shunt trip i

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 9. The breaker shall not be bypassed while one of the diverse trip fea-tures is inoperable except for the time required for performing maintenance to restore the breaker to OPERABLE status.

With tt.e breaker bypassed, apply ACTION 9.

ACTION 13 -

With any reactor trip bypass breaker inoperable, restore the l

bypass breaker to OPERABLE status prior to placing it in service.

1q' (Unit 1)

CATAWBA - UNITS 1 & 2 3/4 3-6 Amendment No.

l (Unit 2)

Amendment No.

TABLE 4.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS a

T, TRIP ANALOG ACTUATING MODES FOR C

CHANNEL DEVICE WHICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACT'JATION SURVEILLANCE d

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED 1.

Hanual Reactor Trip N.A.

N.A.

R(14)

N.A

1. 2.

3*, 4*.5*

2.

Power Range. Neutroa Flux a.

High Setpoint S

D(2. 4).

Q N.A.

N.A

1. 2 M(3. 4).

Q(4. 6).

R(4. 5) b.

Low Setpoint S

R(4)

S/U(1)

N.A.

N.A 1##. 2 3.

Power Range. Neutron Flux.

N.A.

R(4)

Q N.A.

N.A 1, 2 High Positive Rate 4.

Intermediate Range.

S R(4. 5)

S/U(1)

N.A.

N.A If#. 2 Neutron Flux w

5.

Source Range. Neutron Flux S

R(4. 5)

S/U(1).Q(9)

N.A.

N.A 2# 3. 4, 5 6.

Overtemperature aT S

R Q

N.A.

N.A

1. 2 7.

Overpower aT S

R Q

N.A.

N.A 1, 2 8.

Pressurizer Pressure-Low S

R Q

N.A.

N.A -

1 gg mm RE 9.

Pressurizer Pressure-High S

R Q

N.A.

N.A 1, 2 l

88 RA

10. Pressurizer Water Level-High S

R Q

N.A.

N.A 1

l zz

11. Reactor Coolant Flow-Low S

R Q

N.A.

N.A 1

l m

@N CCaa e

vv

TABLE 4.3-1 (Continued) k REACTOR TRIP SYSTEH INSTRUMENTATION SURVEILLANCE REQUIREMENTS w

h TRIP ANALOG ACTUATING MODES FOR CHANNEL DEVICE WHICH c3 CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE g

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED 6

12. Steam Generator Water Level-S R(13)

Q N.A.

N.A 1, 2 l

Low-Low

13. Undervoltage - Reactor Coolant N.A.

R N.A.

Q N.A 1

l Pumps

14. Underfrequency - Reactor N.A.

R N.A.

Q N.A 1

l Coolant Pumps

15. Turbine Trip a.

Stop Valve EH Pressure N.A.

R N.A.

S/U(1. 10)

N.A 1#

- Low g

b.

Turbine Stop Valve Closure N.A.

R N.A.

S/U(1. 10)

N.A If

16. Safety Injection Input from N.A.

N.A.

R N.A

1. 2 I

ESF

17. Reactor Trip System Interlocks a.

Intermediate Range Neutron Flux P-6 N.A.

R(4)

R N.A.

N.A 2##

l b.

Power Range Neutron l

gy sg Flux, P-8 N.A.

R(4)

R N.A.

N.A 1

l gg c.

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

R(4)

R N.A.

N.A 1

l 55

.~

bC aa en vv

.m

TABLE 4.3-1 (Continued) k REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS

?3 TRIP ANALOG ACTUATING MODES FOR c-CHANNEL DEVICE WHICH 5

CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE d

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED b

17. Reactor Trip System Interlocks (Continued) d.

Power Range Neutron Flux. P-10 N.A.

R(4)

R N.A.

N.A 1

l e.

Power Range Neutron Flux. Not P-10 N.A.

R(4)

R N.A.

N.A

1. 2 l

f.

Turbine Impulse Chamber Pressure. P-13 N.A.

R R

N.A.

N.A 1

l

18. Reactor Trip Breaker N.A.

N.A.

M(7. 11)

N.A

1. 2. 3*. 4*

5*

w

19. Automatic Trip and Interlock N.A.

N.A.

M(7)

1. 2. 3*,

4*, 5*

Logic

20. Reactor Trip Bypass N.A.

N.A.

M(7.15)R(16)

N.A

1. 2. 3 *, 4 *. 5' Breakers aa RH aa

LM as al ne vv

TABLE 4.3 1 (Continued)

TABLE NOTATIONS Only if the Reactor Trip System breakers happen to be closed and the Control Rod Drive System is capable of rod withdrawal.

Above P 9 (Reactor Trip on Turbine Trip Interlock) Setp,oint.

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

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

(1) If not performed in previous 31 days.

l (2) Comparison of calorimetric to excore power indication above 15% of RATED THERMAL POWER. Adjust excore channel gains consistent with calorimetric power if absolute difference is greater than 22. The provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

(3) Single point comparison of incore to excore axial flux difference above 15% of RATED THERMAL POWER. Recalibrate if the absolute difference is greater than or equal to 3%. The provisitns of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

(4) Neutron detectors may be excluded from CHANNEL CALIBRATION.

(5) Detector plateau curves shall be obtained, evaluated and compared to manufacturer's data. For the Intermediate Range and Power Range Neutron Flux channels the provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

(6) Incore Excore Calibration, above 75% of RATED THERMAL POWER. The provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

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

(8) Deleted.

(9) Quarterly surveillance in MODES 3*, 4*, and 5* shall also include verification that permissives P 6 and P 10 are in their required state for existing plant conditions by observation of the permissive status light.

(10) Setpoint verification is not applicable.

(11) The TRIP ACTUATING DEVICE OPERATIONAL TEST shall include independent verification of the operability of the Undervoltage and Shunt trips.

(12) Deleted (13) For Unit 1. CHANNEL CALIBRATION shall ensure that the filter time constant i

associated with Steam Generator Water Level Low-Low is adjusted to a value less than or equal to 1.5 seconds, (14) The TRIP ACTUATING DEVICE OPERATIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip circuits for the Manual Reactor Trip Function. The test shall also verify the OPERABILITY of the Bypass Breaker trip circuit (s).

CATAWBA UNITS 1 & 2 3/4 3 12 Amendment No.122(Unit 1)

Amendment No.116(Unit 2)

e INSTRUMENTATION SURVEILLANCE REQUIREMENTS 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 Engineered Safety Features Actuation System 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 demonstrated to be within the limit at least once per 18 months. Each test shall l

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.

CATAWBA UNITS 1 & 2 3/4 3 14 Amendment No.123 (Unit 1)

Amendment No.110 (Unit 2)

1 TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION sn HINIMUM c

TOTAL NO.

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

4.

Steam Line Isolation (Continued)

~

e.

Steam Line Pressure -

3/ steam line 2/ steam line 2/ steam line 3##

15 Negative Rate-High in any steam line

5. Feedwater Isolation l

a.

Automatic Actuation 2

1 2

1. 2 21 Logic and Actuation Relays u

b.

Steam Generator 4/stm. gen.

2/stm. gen.

3/stm. gen.

1, 2 19 E

Water Level-in any oper-in each oper-High-High (P-14) ating stm.

ating stm.

w gen.

gen.

1 c.

T -Low (P-4 Interlock) 4 2

3

1. 2 19 d.

Doghouse Water Level-High 2/ doghouse 1/ doghouse 2/ doghouse

1. 2 27 in any doghouse e.

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

gg

6. Turbine Trip moas a.

Manual Initiation 1

1 1

1.2 25 zz.M b.

Automatic Actuation g

Logic and Actuation gg Relays 2

1 2

1.2 21 l

El or w

TABLE 3.3-3 (Continued) 9 32 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION s

MINIMUM l

TOTAL NO.

CHANNELS CHANNELS APPLICABLE c

si FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION a

o'

6. Turbine Trip (Continued)

G c.

Steam Generator Water Level-High-High (P-14) 4/stm. gen.

2/stm. gen.

3/stm. gen.

1,2 19 in any in each operating stm. operating sim.

gen.

d.

Trip of All Main Feedwater Pumps 2/ pump 1/ pump 1/ pump 1,2#

25 e.

Reactor Trip (P-4) 2 1

2 1,2,3 22 f.

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

7. Containment Pressure Control System a.

Start Permissive 4/ train 2/ train 3/ train 1, 2, 3, 4 16b I

FE gg b.

Termination 4/ train 2/ train 3/ train 1, 2, 3, 4 16b l

aa 39gg

8. Auxiliary Feedwater r c-EF!?

a.

Manual Initiation 1/ train 1/ train 1/ train 1, 2, 3 26 g;Rj b.

Automatic Actuation Logic 2

1 2

1, 2, 3 21 q;q; and Actuation Relavs bh 3=

TABLE 3.3-3 (Continued) e, ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION

-i D

E MINIMUM TOTAL NO.

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

8. Auxiliary Feedwater (Continued) g.

Auxiliary Feedwater o.

Suction Pressure-Low

1) CAPS 5220, 5221, 3/ pump 2/ pump 2/ pump 1, 2, 3 15a l

5222

2) CAPS 5230, 5231, 5232 3/ pump 2/ pump 2/ pump 1,2,3 15a l

9. Containment Sump Recirculation a.

Automatic Actuation 2

1 2

1,2,3,4 14 Logic and Actuation Relays w5 b.

Refueling Water Storage E

cp Tank Level-Low 4

2 3

1,2,3,4 16a l

N

~

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

kk gg 10. Loss of Power RR gg a.

4 kV Bus Undervoltage-3/ Bus 2/ Bus 2/ Bus 1, 2, 5, 4 15 Loss of Voltage 55

'h b.

4 kV Bus Undervoltage-4 Grid Degraded Voltage 3/ Bus 2/ Bus 2/ Bus 1, 2, 3, 4 15

11. Control Room Area

^^

Ventilation Operation ee N-a.

Automatic Actuation Logic

~~

and Actuation Relays 2

1 2

All 24

4 e

52

??$tE 3.3-3 (Continued) 50 ENGINEERED SAFETY r2ATURES ACTUATION SYSTEM INSTRUMENTATION Es i

MINIMUM TOTAL NO.

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

a

"' 11. Control Room Area

l Ventilation Operation (Continued) b.

Loss-of-Offsite Power 3

2 2

1, 2, 3 15a l

i c.

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

l

12. Contlinment Air Return and Hydrogen Skimmer Operation i

a.

Manual Initiation 2

1 2

1,2,3,4 18 w

b.

Automatic Actuation Logic 32 and Actuation Relays 2

1 2

1,2,3,4 14a l-w d3 c.

Containment Pressure-High-High-4 2

3 1,2,3 16

13. Annulus Ventilation Operation kk aa a.

Manual Initiation 2

1 2

1,2,3,4

' 18 b.

Automatic Actuation Logic ma and Actuation Relays 2

1 2

1,2,3,4 14a l

N&

c.

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

$N

14. Nuclear Service Water Operation EF!?

a.

Manual Initiation 2

1 2

1,2,3,4 18 en 83 -.

b.

Automatic Actuation Logic and Actuation Relays 2

1 2

1,2,3,4 21a l

1 4

4

... ~. -. - -, ~

-..~v e

.,e

TABLE 3.3-3 (Continued) 9g ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 5*

MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE E

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION a

14. Nuclear Service Water Operation

-C (Continued) c.

Loss-of-Offsite Power 3

2 1.2.3 15a l

d.

Containment Spray See Item 2. above for all Containment Spr. initiating functions and requirements.

e.

Phase "B" Isolation See Item 3.b. above for all Phase "B" Isolation initiating functions and requirements.

f.

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

9 Suction Transfer-Low W

Pit Level (Units 1 and 2) m Y

2 Out of 3 Logic 3/ pit 2/ pit (ei+.her 2/ pit 1.2.3.4 29 0

pit)

15. Emerwns.y Diesel Generator Ooeration (Diesel Building ventilation Operation. Nuclear Service Water Operation)

FF a.

Manual Initiation 2

1 2

1.2.3.4 18 an b.

Automatic Actuation Logic and Actuation Relays 2

1 2

1.2.3.4 21 m

l c.

Loss-of-Offsite Power 3

2 2

1.2.3.4 15a py d.

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

16. Auxiliary Building Filtered gg Exhaust Operation a.

Manual Initiation 2

1 2

1.2.3.4 18 ro -

b.

Automatic Actuation Logic 2

1 2

1.2.3.4 21a l

and Actuation Relays

TABLE 3.3-3 (Continued) k.

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION c*i D;

16. Auxiliary Building Filtered Exhaust Operation (Continued)

E c.

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

17. Diesel Building Ventilation Operation a.

Manual Initiation 2

1 2

1.2.3.4 18 b.

Automatic Actuation Logic and Actuation Relays 2

1 2

1.2.3.4 21a l

c.

Emergency Diesel Generator Operation See Item 15. above for all Emergency Diesel Generator Operation initiating vg functions and requirements.

18. Engineered Safety Features Actuation System Interlocks a.

Pressurizer Pressure.

3 2

2

1. 2. 3 20 P-11 b.

Pressurizer Pressure.

3 2

2

1. 2. 3 20 yP not P-11 e 13 EE c.

Low-Low T,,, P-12 4

2 3

1. 2. 3 20 mR AA d.

Reactor Trip. P-4 2

2 2

1, 2. 3 22 zz PP e.

Steam Generator Water 4/stm. gen.

2/stm. gen.

3/sta.

1. 2. 3 20 l

3 Level. P-14 in any gen. in j

gm operating each gg stm. gen, operating i

stm. gen.

l E

l l

o TABLE 3.3-3 (Continued 1-TABLE NOTATIONS

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

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

ACTION STATEMENTS ACTION 14 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, be in at least HOT STANDBY 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 ; how-ever, 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 surveil-lance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

ACTION 14a - 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 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 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

ACTION 15 -

With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceed until performance of the next required ANALOG CHANNEL OPERATIONAL TEST provided the inoperable channel is placed in the tripped condition within 6 l

hours.

ACTION 15a - With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceed until performance of the next required ANALOG CHANNEL OPERATIONAL TEST provided the inoper-able channel is placed in the tripped condition within I hour.

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 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 l

Specification 4.3.2.1.

ACTION 16a - 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 3

Channels OPERABLE requirement is met.

One additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.

CATAWBA - UNITS 1 & 2 3/4 3-25 Amendment No. 122 (Unit 1)

Amendment No. 116 (Unit 2)

TABLE 3.3-3 (Continued)

TABLE NOTATIONS (Continued)

ACTION 16b - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

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

The Minimum Channels OPERA 8LE requirement is met; however, one additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for sur-veillance testing of other channels per Specification 4.3.2.1.

ACTION 17 - With less than the Minimum Channels OPERABLE requirement, opera-tion may continue provided the containment purge supply and exhaust valves are maintained closed.

ACTION 18 - 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 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 .

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:

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 l

j 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 sur-l veillance testing of other channels per Specification 4.3.2.1.

ACTION 20 -

With less than the Minimum Channels OPERABLE, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months deter-mine by observation of the associated permissive status light (s) that the interlock is in its required state for the existing plant 4

condition, or apply Specification 3.0.3.

ACTION 21 - 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 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 21a - 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 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 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1 provided the other channel is OPERABLE.

ACl!0N 22 - 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 H0T 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 .

CATAWBA - UNITS 1 & 2 3/4 3-26 Amendment No. 122 (Unit 1)

Amendment No. 116 (Unit 2)

TABLE 3.3-3 (Continued)

TABLE NOTATIONS (Continued)

ACTION 23 -

With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.4.

ACTION 24 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE, 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 Area Ventilation System with flow through the HEPA filters and activated carbon adsorbers.

ACTION 25 -

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 .

ACTION 26 -

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 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 27 -

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 4.3.2.1 provided the other channel is OPERABLE.

ACTION 28 -

Deleted.

l ACTION 29 -

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

a.

With one channel inoperable, place the inoperable channel in the tripped condition within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and ensure the Minimum Channels OPERABLE requirement is met. One addi-tional 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 sur-veillance testing of other channels per Specification 4.3.2.1; or b.

With less than the Minimum Number of Channels OPERABLE align the Nuclear Service Water System for Standby Nuclear Service Water Pond recirculation within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-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 , at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and at least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

CATAWBA - UNITS 1 & 2 3/4 3-26a Amendment No.

122 (Unit 1)

Amendment No.

116 (Unit 2) i

~

j' TABLE 4.3-2 h-ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION

{

SURVEILLANCE REQUIREMENTS E

TRIP Q

ANALOG ACTUATING MODES CHANNEL DEVICE MASTER SLAVE FOR WHICH E

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CHECK J.IBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED 1.

Safety Injection (Reactor Trip.

Phase "A" Isolation. Feedwater Isolation. Control Room Area Ventilation Operation. Auxiliary Feedwater-Motor-Driven Pump.

i Purge and Exhaust Isolation.

i Annulus Ventilation Operation, Auxiliary Building Filtered Exhaust Operation. Emergency R

Diesel Generators Operation, t

Component Cooling Water.

Y Turbine Trip, and Nuclear A

Service Water Operation) l a.

Manual Initiation N.A.

N.A.

R N.A.

N.A N.A.

1. 2. 3. 4 b.

Automatic Actua-N.A.

N.A.

M(1)

Q

1. 2. 3. 4 t

tion Logic and Actuation Relays c.

Containment S

R Q

N.A.

N.A N.A.

1. 2. 3 l

[

g Pressure-High SE d.

Pressurizer S

R Q

N.A.

N.A N.A.

1. 2. 3 l

Pressure-Low i

no gg e.

Steam Line S

R Q

N.A.

N.A N.A.

1. 2. 3 l

Pressure-Low 3g on

.88 2.

Containment Spray Ea-a.

Manual Initiation N.A.

N.A.

R N.A.

N.A N.A.

1. 2. 3. 4 l

UC b.

t.utomatic Actua-N.A.

N.A.

M(1)

Q 1,2.3,4 tion Logic'and Actuation Relays

g TABLE 4.3-2 (Continued) 5g ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS g

TRIP q

ANALOG ACTUATING MODES m

CHANNEL DEVICE MASTER SLAVE FOR WHICH g

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE N

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC #EST TEST TEST IS REQUIRED 2.

Containment Spray (Continued) c.

Containment S

R Q

N.A.

N.A N.A.

1. 2, 3 l

Pressure-High-High 3.

Containment Isolation a.

Phase "A" Isolation e.i S

1) Hanual Initia-N.A.

N.A.

R N.A.

N.A N.A 1.2.3.4 y

tion

2) Automatic Actua-N.A.

N.A.

M(1)

Q 1, 2. 3. 4 tion Logic and Actuation Relays

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

^

b.

Phase "B" Isolation (Nuclear Service Water Operation) g;e

1) Manual Initia-N.A.

N.A.

R N.A.

N.A N.A 1.2.3.4 i

gg tion

o. a.

S3

2) Automatic Actua-N.A.

N.A.

H(1)

Q

1. 2, 3. 4 AA tion Logic and

..gg Actuation Relays Z

3) Containment S

R Q

N.A.

N.A N.A.

1. 2, 3 S

Pressure-High-High no me c.

Purge and Exhaust Isolation

1) Manual Initia-N.A.

N.A.

R N.A.

N.A N.A.

1. 2. 3. 4 tion

t w '

TABLE 4.3-2 (Continued) g

--e ENGINEER SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 3=

SURVEILLANCE REQUIREMENTS c

TRIP 5

ANALOG ACTUATING MODES i

d CHANNEL DEVICE MASTER SLAVE FOR WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE E

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

3.

Containment Isolation t

(Continued)

2) Automatic Actua-N.A.

N.A.

M(1)

Q

1. 2. 3. 4 tion Logic and Actuation Relays

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

u E

4.

Steam Line Italation u

a.

Manual Initiation N.A.

N.A.

R N.A.

N.A N.A.

1. 2. 3 l

g b.

Automatic Actuation N.A.

N.A N.A N.A.

M(1)

Q

1. 2. 3 -

I Logic and Actuation l

Relays c.

Containment S

R Q

N.A.

N.A N.A.

1. 2. 3 l

Pressure-High-High kk d.

Steam Line S

R Q

N.A.

N.A N.A.

1. 2. 3 l

RR Pressure-Low 22

%a e.

Steam Line Pressure-S R

Q N.A.

N.A.

N.A N.A.

3 Negative Rate-High l

zz OO ID 5.

Feedwater Isolation

'T Es a.

Automatic Actuation N.A.

N.A.

M(1)

Q 1, 2

$;7 Logic and Actuation Relays i

m

__.-.__________-_..,~m-__

TABLE 4.3-2 (Continued)

Q ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION g

SURVEILLANCE REQUIREMENTS r5 TRIP ANALOG ACTUATING H0 DES E

CHANNEL DEVICE MASTER SLAVE FOR WHICH Q

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED C

N 5.

Feedwater Isolation (Continued) b.

Steam Generator S

R Q

N.A.

1. 2 l

Water Level-High-High (P-14) c.

T -Low (P-4 INerlock)

S R

Q N.A.

N.A.

1. 2 l

d.

Doghouse Water Level-High N.A.

N.A.

R N.A.

N.A.

1, 2 l

e.

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

g Y

6.

Turbine Trip e

a.

Manual Initiation N.A.

N.A.

R N.A.

N.A.

1. 2 b.

Automatic N.A.

N.A.

H(1)

Q

1. 2 Actuation Logic and Actuation Relays c.

Steam Generator S

R Q

N.A.

1. 2 l

Water level-High-High kk (P-14)

=3 kk d.

Trip of All Hain N.A.

N.A.

R N.A.

N.A.

1, 2 l

gg Feedwater Pumps ff e.

Reactor Trip (P-4)

N.A.

R N.A.

N.A.

1, 2. 3 l

h f.

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

EE aa 7.

Containment Pressure Control System r+

m-

~

l a.

Start Permissive S

R H

N.A.

1,2,3.4 l

b.

Termination S

R H

N.A.

N.A N.A.

N.A.

1,2.3,4

TABLE 4.3-2 (Continued)

O ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION p

SURVEILLANCE REQUIREMENTS s

TRIP ANALOG ACTUATING MODES c5 CHANNEL DEVICE MASTER SLAVE FOR WHICH d

CHANNEL CHANNEL C}W4NEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED E

8.

Auxiliary Feedwater a.

Manual Initiation N.A.

N.A.

R N.A.

N.A N.A.

1. 2. 3 b.

Automatic Actuation N.A.

N.A N.A.

N.A.

M(1)

M(1) 0

1. 2. 3 Logic and Actuation Relays c.

Steam Generator 5

R Q

N.A.

N.

N.A

1. 2. 3 l

Water Level-Low-Low d.

Safety Injection See Item 1. above for all Safety injection Surveillance Requiremants.

e.

Loss-of-Offsite N.A.

R N.A.

M(3)

N.A.

N.A N.A

1. 2. 3 m

Power f.

Trip of All Main N.A.

N.A.

R N.A.

N.A N.A

1. 2 feedwater Pumps g.

Auxiliary Feedwater Suction Pressure-Low N.A.

N.A.

R N.A.

N.A N.A.

1. 2. 3 pp

9. Containment Sump gg Recirculation aa ll a.

Automatic Actuation N.A.

N.A.

M(1)

Q

1. 2. 3. 4 Logic and Actuation gg Relays b.

Refueling Water S

R H

N.A.

N.A N.A.

1. 2. 3. 4 "ga$

Storage Tank Level -

cc Low Coincident With hh Safety Injection See Item 1. above for all Safety Injection Surveillance Requirements.

SC

TABLE 4.3-2 (Continued) 9 ENGINEERED SAFETV TEATURES ACTUATION SYSTEM INSTRUMENTATION 5;'

SURVEILLANCE RE0VIREMENTS E>

TRIP ANALOG ACTUATING MODES E

CHANNEL DEVICE MASTER SLAVE FOR WHICH Z

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE

,' FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REOUIRED

10. Loss of Power

)

a.

4 kV Bus N.A.

R N.A.

M (2)

N.A.

N.A N.A.

1, 2, 3, 4 Undervoltage-Loss of Voltage b.

4 kV Bus N.A.

R N.A.

M (2)

N.A.

N.A N.A.

1,2,3,4 Undervoltage-Grid Degraded Voltage l

11. Control Room Area Ventilation Operation a.

Automatic Actuation N.A.

N.A.

M(1)

Q All logic and Actuation w1 Relays l

w b.

Loss-of-Offsite N.A.

R N.A.

N.A N.A.

1, 2, 3 t

i Power c.

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

12. Containment Air Return and Hydrogen Skimmer g{

Operation aa a.

Manual Initiation N.A.

N.A.

R N.A.

N.A N.A.

1, 2, 3, 4 gg b.

Automatic N.A.

N.A.

M(1)

Q 1, 2, 3, 4 ma Actuation Logic and 3

EF Actuation Relays c.

Containment S

R Q

N.A.

N.A N.A.

1, 2, 3 l

Q Pressure-High-High

13. Annulus Ventilation gg g, =

Operation a.

Manual Initiation N.A.

N.A.

R N.A.

N.A N.A.

1, 2, 3, 4 l

t

~_

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS h

TRIP ANALOG ACTUATING M00t CHANNEL DEVICE MASTER SuVE FOR kHICH E

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RE MY RELAY SURVEILLANCE

]

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED 5

17. Diesel Building Ventilation Operation a.

Manual Initiation N.A.

N.A.

R N.A.

N.A.

1,2.3.4 b.

Automatic N.A.

N.A.

M(1)

Q

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

Emergency Diesel See Item 15. above for all Emergency Diesel Generator Operation Surveillance Generator Operation Requirements.

18. Engineered Safety Features y

Actuation System Interlocks O

a.

Pressurizer N.A.

R Q

N.A.

1. 2. 3 l

Pressure P-11 b.

Pressurizer N.A.

R Q

N.A.

N.A 1, 2. 3 l

Pressure, not P-11 c.

Low-Low Tm. P-12 N.A.

R Q

N.A.

N.A. '

N.A.

1. 2. 3 l

kk d.

Reactor Trip. P-4 N.A.

N.A.

R N.A.

N.A.

1. 2. 3 Ra B2 e.

Steam Generator S

R Q

N.A.

M(1)

Q

1. 2. 3 l

AE Water Level. P-14 55 TABLE NOTATIONS

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

EE (2) Honthly testing shall consist of voltage sensor relay testing excluding actuation of load shedding diesel start. and time -

RR delay timers.

(3) Monthly testing shall consist of relay testing excluding final actuation of the pumps or valves.

S'O (4) Deleted.

l (5) Surveillance Requirements must be met on common (shared) portions of the Nuclear Service Water System when either unit is in MODE 1. 2. 3. or 4.

Surveillance Requirements must be met on unit-specific portions of the Nuclear Service Water System only when the unit is in MODE 1. 2. 3. or 4.

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 and suffi-cient redundancy is maintained to permit a channel to be out of service for testing and 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 OPERABILITY 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 Sur-veillance Requirements specified for these systems ensure that the overall system func-tional 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 j

been determined in accordance with WCAP 10271, " Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System," and supple-ments to that report. Surveillance intervals and out of service times were determined based on maintaining an appropriate level of reliability of the Reactor Protection Sys-tem and Engineered Safety Features. instrumentation. The NRC Safety Evaluation Reports for the WCAP 10271 series were provided in letters dated February 21. 1985 from C. O.

Thomas (NRC) to J. J. Sheppard (WOG), February 22, 1989 from C. E. Rossi (NRC) to R. A.

Newton (WOG). and April 30, 1990 from C. E. Rossi (NRC) to G. T. Goering (WOG). From these reports, additional conditions are required to support the WCAP, including: (1) common cause evaluation for failure in the channels changed to the quarterly test fre-i quency and additional testing for plausible common cause failures, (2) installed hard-ware capabilities for testing in the bypass mode, and (3) provisions for demonstrating appropriate adjustments for instrument setpoint methodology to offset the drift anticipated as a result of a less frequent surveillance.

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.

Operation with Setpoints less conser-vative 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.

CATAWBA UNITS 1 & 2 B 3/4 3 1 Amendment No. ]P(Unit 1)

AmendmentNo.1d(Unit 2)

ML20071J179

Text

Attachment:

Attachment:

Navigation menu

Search