ML20012C734

Amends 32 & 23 to Licenses NPF-35 & NPF-52,respectively, Modifying Tech Specs to Permit Operation Up to Full Power W/ Upper Head Injection Accumulator Sys Removed

ML20012C734
Person / Time
Site:	Catawba
Issue date:	11/10/1987
From:	Crocker L Office of Nuclear Reactor Regulation
To:
Shared Package
ML20012C735	List: ML20012C734 ML20012C736 ML20012C737
References
NUDOCS 9003230140
Download: ML20012C734 (28)

Text

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UNITED STATES

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,'%j-NUCLEAR REGULATORY COMMISSION l.

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W ASHINGT ON, D. C. 20$$$

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p DUKE POWER COMPANY l

NORTH CAROLINA ELECTRIC MEMBERSHIP CORPORATION SALUDA RIVER ELECTRIC COOPERATIVE, INC.

DOCKET NO. 50-413 CATAWBA NUCLEAR STATION, UNIT 1-AMENDMENT TO FACILITY OPERATING LICENSE I

Amendment No. 32 License,No NPF-35 1.

The Nuclear Regulatory Comission (the Comission) 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 June 12, 1987, and supplemented June 23 and August 12, 1987 complies with the standards and-requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Comission's rules and regulations as set forth in 10 CFR Chapter I; B.

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

There is reasonable assurance: (1)thattheactivitiesauthorizedby this amendment can be conducted without endangering the health and safety of the puolic, and (ii) that such activities will be conducted in compliance with the Comission's regulations set forth in 10 CFR

-Chapter I; D.

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

$ 21 co mon defense and security or to the health and safety of the public; cn E.

The issuance of-this amendment is in accordance with 10 CFR Part 51 g8 of the Comission's regulations and all applicable requirements have

' go.

been satisfied.

M 2.

Accordingly, the license is hereby amended by page chan es to the Technical Specifications as indicated in the attachments to this icense amendment and

'$6 Paragraph 2.C.(2) of Facility Operating License No. NPF-35 is hereby amended gg to read as follows:

to a

-Q (2) Technical Specifications and Environmental Protection Plan cc 8So.

The Technical Specifications contained in Appendix A, as revised through Amendment No. 32, and the Environmental Protection Plan

);

2 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.

f F0 THE NUCLEAR REGULATORY CO WISSION W

CNhACA Lawrence P. Crocker, Acting Director Project Directorate 11-3 Division of Reactor Projects 1/11

Attachment:

Technical Specification Changes Date of Issuance: November 10, 1987 l

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UNITED STATES

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NUCLEAR REGULATORY COMMISSION a

WASHINGTON, D. C. 20555 g

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DUKE POWER COMPANY-NORTH CAROLINA MUNICIPAL POWER AGENCY NO. 1 PIEDMONT MUNICIPAL POWER AGENCY DOCKET NO. 50-414 CATAWBA NUCLEAR STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 23 License No. NPF-52 1.

The Nuclear Regulatory Comission (the Comission) 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 June 12, 1987, and supplemented June 23 and August 12, 1987, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Comission's ules and regulations as set forth in 10 CFR Chapter I; B.

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

There is reasonable assurance: (1) 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 fn compliance with the Commission's regulations set forth in 10 CFR Chapter I; 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;

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

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachments to this license amendment and Paragraph 2.C.(2) of Facility Operating License No. NPF-52 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 23, and the Environmental Protection Plan i

!E j

2 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 Specificaticns and the Environmental Protection Plan.

3.

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

F0 THE NUCLEAR REGULATORY C0W.lSS10f4

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's Lawrence P. Crocker, Acting Director Project Directorate II-3 Division of Reactor Projects 1/11

Attachment:

Technical Specification Changes Date of Issuance:

November 10, 1987 L

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1:

ATTACHMENT TO LICENSE AMENDMENT NO.

FACILITY OPERATING LICENSE NO NPF-35 DOCKET NO. 50-413 AND TO LICENSE AMENDMENT NO.

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

Amended Overleaf Page Page 3/4 3-75 3/4 3-76 3/4 4-22 3/4 4-21 3/4 5-1 3/4 5-la 3/4 5-2 3/4 5-3 3/4 5-4 3/4 6-7 3/4 6-23 3/4 6-24 3/4 6-31 3/4 6-32 l

3/4 8-23 3/4 8-24 3/4 8-46 3/4 8-45 3/4 8-47 3/4 8-48 B 3/4 5-1 B 3/4 5-2 B 3/4 5-3 l

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"t TABLE 3.3-11 (Continued) n h

FIRE DETECTION INSTRUMENTS 5

h FIRE MINIMUM INSTRUMENTS OPERABLE

• z ZONE DESCRIPTION LOCATION SMOKE FLAME HEAT FUNCTION **

N 69 Cable Room CC-59 E1.577 + 0 18 0

15 A

H 71 Elect Pene. Room CC-51 E1.594 + 0

'10 0

0 A

P 72 Control Room CC-56 E1.594 + 0' 23 0

6 A

N 73 Vent. Equip. Room FF-56 E1.594 + 0 9

0 0

A 74 Aisles / Cables LL-56 E1.594 + 0 25 0

25 A

76 Aisles / Cables PP-54 E1.594 + 0 15 0

15 A

79 Elect. Pene. Room BB-63 E1.594 + 0 11 0

0 A

80 Control Room BB-59 E1.594 + 0 22 0

6 A

81 Ven. Equip. Room FF-58 E1.594 + 0 12 0

0 A

~

82 Aisles / Cables KK-58 E1.594 + 0 28 0

27 A

R 84 Aisles / Cables NN-58 E1.594 + 0 17 0

17 A

89 Fuel Pool Area #1 PP-50 E1.605 + 10 19 7

19 A

y 90 Fuel Pool Area (Unit 2)

PP-64 E1.605 + 10 19 7

19 A

g 128*

UHI Bldg.

HH-44 E1.550 + 0 2

3 2

A l

129 Fuel Pool Purge Room NN-50 E1.631 + 6 6

0 6

A 130*

UHI Bldg. (Unit 2)

HH-71 El.594 + 0 2

3 2

A l

131 Reactor Bldg.

0*-45*

Be1.

E1.565 + 3 4

0 0

A 132 Reactor B1dg.

45*-90*

Be1.

E1.565 + 3 3

0 0

A 133 Reactor Bldg.

90 -135*

Be1.

E1.565 + 3 4

0 0

A 134 Reactor Bldg.

135*-180 Be1.

E1.565 + 3 5

0 0

A 135 Reactor Bldg.

180*-225' Be1.

El.565 + 3 4

0 0

A 55 136 Reactor Bldg.

270*-315*

Be1.

E1.565 + 3 3

0 0

A EE 137 Reactor B1dg.

315*-0*

Be1.

E1.565 + 3 8

0 0

A 55 138 Reactor Bldg.

0*-45*

Bel.

E1.586 + 3 6

0 0

A 55 139 Reactor Bldg.

45"-90*

Be1.

E1.586 + 3 4

0 0

A zz 140 Reactor Bldg.

90*-135' Be1.

E1.565 + 3 3

0 0

A PP 141 Reactor Bldg.

135*-180 Be1.

E1.586 + 3 8

0 0

A OM 142 Reactor Bldg.

180*-225*

Be1.

E1.586 + 3 5

0 0

A 143 Reactor Bldg.

315*-0 Bel.

E1.586 + 3 5

0 0

A

^^

EE 144 Reactor Bldg.

0*-45*

.Be1.

E1.593 + 2\\

14-0 0

A 33 145 Reactor Bldg.

45*-90 Be1.

E1.593 + 2\\

17 0

0 A

=

146 Reactor Bldg.

90-135*

Be1.

E1.593 + 2 11 0

0 A

• Upon the disconnection of the UHI System from the Reactor Coolant System, these specifications are no longer applicable.

f *J TABLE 3.3-11 (Continued) 9 g

FIRE DETECTION INSTRUMENTS 5

2-MINIMUM INSTRUMENTS OPERABLE

• h FIRE ZONE DESCRIPTION LOCATION

{

SMOKE FLAME HEAT FUNCTION **

147 Reactor Bldg.

135'-180' Be1. E1.593 + 2 10 0

O A

148 Reactor Bldg.

180'-225' Be1. E1.593 + 2 2

0 0

A.

149 Reactor B1dg.

315'-0*

Be1. E1.593 + 2%

7 0

0 A

150 Reactor Bldg. (Unit 2) 0*-45' Be1. E1.565 + 3 4

0 0

A u

151 Reactor B1dg. (Unit 2) 45'-90' Be1. E1.565 + 3 3

0 0

A 152 Reactor Bldg. (Unit 2) 90'-135' Be1. E1.565 + 3

'4 0

0 A

153 Reactor Bldg. (Unit 2) 135'-180*

Se1. E1.565 + 3 5

0 0

A 154 Reactor Bldg. (Unit 2) 180*-225' Be1. E1.565 + 3 3

0 0

A 155 Reactor Bldg. (Unit 2) 270*-315' Be1. E1.565 + 3 4

0 0

A 156 Reactor Bldg. (Unit 2) 315'-0*

Be1. E1.565 + 3 6

0 0

A R

157 Reactor 81dg. (Unit 2) 0*-45' Be1. E1.586 + 6 6

0 0

A 158 Reactor Bldg. (Unit 2) 45'-90' Be1. E1.586'+ 6 4

0 0

A i

y 159 Reactor Bldg. (Unit 2) 90'-135' Be1. E1.586 + 6 3

0 0

A g

160 Reactor B1dg. (Unit 2) 135*-180' Be1. E1.586 + 6 8

0 0

A 161 Reactor Bldg. (Unit 2) 180*-225' Be1. E1.586 + 6 5-0 0

A 162 Reactor Bldg. (Unit 2) 315'-0*

Be1. E1.586 + 6 5

0 0

A 163 Reactor B1dg. (Unit 2) 0*-45' Be1. E1.593 + 2%

13 0

0 A

164 Reactor Bldg. (Unit 2) 45*-90*

Be1. E1.593 + 2 17 0

0 A

165 Reactor Bldg. (Unit 2) 90'-135' Be1. E1.593 + 2 13 0

0 A

166 Reactor B1dg. (Unit 2) 135'-180' Be1. E1.593 + 2%

10 0

0 A

i l

167 Reactor Bldg. (Unit 2) 180*-225' Be1. E1.593 + 2%,

2 0

0 A

168 Reactor B1dg. (Unit 2) 315'-0*

Be1. E1.593 + 2%

/

0 0

A 169 RCP-1A Reactor Bldg.

E1.593 + 2 0

0 1

A 170 RCP-1B Reactor'B1dg.

E1.593 + 2%

0 0

1 A

171 RCP-IC Reactor B1dg.

E1.593 + 2 0

0 1

A*

172 RCP-10

. Reactor B1dg.

E1.593 + 2%

0 0

,1 A

173 RCP-2A 45' Be1. E1.593 + 2%

0 0

1 A

174 RCP-28 135' Be1. E1.593 + 2%

0 0

1 !

A 175 RCP-2C 225' Be1. E1.593 + 2 0-0 1

A 176 RCP-2D 315*

Be1. E1.593 + 2%

0 0

1 A

i 177 Filter Bed Unit IB Reactor Bldg.

Be1. E1.565 + 3 2

0 2

.A 178 Filter Bed Unit 1A Reactor B1dg.

Be1. E1.565 + 3, 2

0 2

A I

r r

r

10

.D '

REACTOR COOLANT SYSTEM I- -

SURVEILLANCE REQUIREMENTS 4.4.6.2.1 Reactor Coolant System leakages shall be demonstra.ted to be within each of the above limits by:

a.

Monitoring the containment atmosphere gaseouc radioactivity monitor at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />; b.

Monitoring the containment floor and equipment sumps inventory and discharge at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />; c.

Measurement of the CONTROLLED LEAKAGE to the reactor coolant pump seals when the Reactor Coolant System pressure is 2235 1 20 psig at least once per 31 days.

The provisions of Specification 4.0.4'are not applicable for entry into MODE 3 or 4; d.

Performance of a Reactor Coolant System water inventory balance at least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; and e.

Monitoring the reactor head flange leakoff at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

.n*

4.4.6.2.2 Each Reactor Coolant System Pressure Isolation Valve specified in Table 3.4-1 shall be demonstrated OPERABLE by verifying leakage to be within

(

its limit:

a.

At least once per 18 months, b.

Prior to entering MODE 2 whenever the plant has been in COLD SHUTDOWN for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or more and if leakage testing has not been performed in the previous 9 months, c.

Prior to returning the valve to service following maintenance, repair or replacement work on the valve, and d.

Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following valve' actuation due to automatic or manual action or flow through the valve.

The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4.

CATAWBA - UNITS 1 & 2 3/4 4-21

s a

. TABLE 3.4-1 REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES VALVE NUMBER FUNCTION V

NI59 Accumulator Discharge Ni60 Accumulator Discharge NI70_

Accumulator Discharge NI71 '

' Accumulator Discharge NIB 1 Accumualtor Discharge NI82 Accumulator Discharge NI93 Accumulator Discharge NI94 Accumulator Discharge NI124.

Safety Injection (Hot Leg)

NI125 Residual Heat Removal (Hot Leg)

NI126 Safety Injection (Hot Leg)

NI128-Safety Injection (Hot Leg)

N1129 Residual Heat Removal (Hot Leg)

NI134-Safety Injection (Hot Leg)

NI156 Safety Injection (Hot Leg)

NI157 Safety Injection (Hot Leg)

NI159 Safety Injection (Hot Leg)

NI160 Safety Injection (Hot Leg)

NI165.

Safety Injection / Residual Heat Removal (Cold Leg)

NI167 Safety Injection / Residual Heat Removal (Cold Leg)

NI169 Safety Injection / Residual Heat Removal (Cold Leg)

NI171 Safety Injection / Residual-Heat Reinoval (Cold Leg)-

NI175 Safety Injection / Residual Heat Removal (Cold Leg)

N1176 Safety Injection / Residual Heat Removal (Cold Leg)

NI180 Safety Injection / Residual Heat Removal (Cold Leg)

NI181 Safety Injection / Residual Heat Removal (Cold Leg) f NI248

. Upper Head Injection 9 NI249 Upper Head Injection NI250 Upper Head Injectior.

_i' NI251..

Upper Head Injection

• Note 1 NI252 Upper Head Injection L NI253 UpperHeadInjectionJ Note:1:

Upon the disconnection of the UHI System from the heactor Coolant System, this specification is no longer applicable.

CATAWBA - UNITS 1 & 2 3/4 4-22 Amendment No.32(Unit 1)

Amendment No.23(Unit 2)

g m

3'/4. 5'-

EMERGENCY CORE COOLING SYSTEMS 1

3/4.5.I' ACCUMULATORS

-1 COLO LEG INJECTION LIMITING CONDITION FOR OPERATION 3.5.1.1.1 Each cold leg injection accumulator shall be OPERABLE with:

l a.

The discharge isolation valve open, b.

A contained borated water volume of between 7853 and 8171 gallons, c.

A boron concentration of between 1900 and 2100 ppm, d.

A nitrogen cover pressure of between 385 and 481 psig, and e.

A water level and pressure channel OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3*.

(UHI System Operable)

ACTION:

a.

With one cold leg injection accumulator inoperable, except as a result of a closed isolation valve or boron concentration less than 1900 ppm, l

restore the inoperable accumulator to OPERABLE status within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, b.

With-one cold leg injection accumulator inoperable due to the isolation valve being closed, either immediately open the isolation valve or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN l

L within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

c.

With one accumulator inoperable due to boron concentration less than 1900 ppm and:

1)

The volum'e weighted average boron concentration of the three limiting accumulators 1900 ppm or greater, restore the inoperable accumulator to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of the low boron determination or be in at least HOT STANDBY within the next l

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pressure to less than 1000 psig l

within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

2)

The volume weighted average boron concentration of the three limiting accumulators less than 1900 ppm but greater than 1500 ppm, restore the inoperable accumulator to OPERABLE status or return the volume weighted average boron concentration of l

the three limiting accumulators to greater than 1900 ppm and l

enter ACTION c.1 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> of the low boron determination l

or be in HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pres-l surizer pressure to less than 1000 psig within the following l

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Pressurizer pressure above 1000 psig.

CATAWBA - UNITS 1 & 2 3/4 5-1 Amendment No. 32 (Unit 1)

Amendment No. 23 (Unit 2) i

l i

' EMERGENCY CORE COOLING SYSTEMS LIMITING CONDITION FOR OPERATION (Continued) 3)

The volume weighted average boron concentration of the three limiting accumulators 1500 ppm or less, return the volume weighted average boron concentration of the three limiting accumulators to greater than 1500 ppm and enter ACTION c.2 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of the low boron determination or be in HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pres-sure to less than 1000 psig within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.5.1.1.1.1 Each cold leg injection accumulator shall be demonstrated l

OPERABLE:

a.

At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by:

1)

Verifying, by the absence of alarms, the contained borated water volume and nitrogen cover pressure in the tanks, and 2)

Verifying that each cold leg injection accumulator isolation valve is open.

l 1.

l l

g CATAWBA - UNITS 1 & 2 3/4 5-la Amendment No,32 (Unit 1)

Amendment No.23 (Unit 2)

1 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ACCUMULATORS COLD LEG INJECTION LIMITING CONDITION FOR OPERATION 3.5.1.1.2 Each cold leg injection accumulator shall be OPERABLE with:

a.

The discharge isolation valve open, b.

A contained borated water volume of between-7704 and 8004 gallons, c.

A boron concentration of between 1900 and 2100 ppm, d.

A nitrogen cover pressure of between 585 and 678 psig, and e.

A water level and pressure channel OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3*.

(VHI physically disconnected; Cold Leg Accumulators and discharge paths suitably modified)

ACTION:

a.

With one cold leg injection accumulator inoperable, except as a result of a closed isolation valve, restore the inoperable accumulator to OPERABLE status within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

i 1

1 b.

With one cold leg injection accumulator inoperable due to the l

isolation valve being closed, either immediately open the isolation valve or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN l-within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.5.1.1.2.1 Each cold leg injection accumulator shall be demonstrated l

OPERABLE:

a.

At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by:

1)

Verifying, by the absence of alarms, the contained borated water volume and nitrogen cover pressure in the tanks, and 2)

Verifying that each cold leg injection accumulator isolation valve is open.

• Pressurizer pressure above 1000 psig.

CATAWBA - UNITS 1 & 2 3/4 5-2 Amendment No. 32 (Unit 1)

Amendment No. 23 (Unit 2)

.=

E$ERGENCYCORECOOLINGSYSTEMS SURVEILLANCE REQUIREMENTS-(Continued)

~

b.

At least once per 31 days and within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after each solution volume increase of greater than or equal to 75 gallons by verifying the boron concentration of the accumulator solution; c.

At-least once per 31 days when the Reactor Coolant System pressure is above 2000 psig by verifying that power is removed from the isolation valve operators on Valves NI54A, NI65B, NI76A, and NIB 8B and that the respective circuit breakers are padlocked; and d.

At least once per 18 months by verifying that each cold leg injection accumulator isolation valve opens automatically under

-each of the following conditions:**

1)

When an actual or a simulated Reactor Coolant System pressure signal exceeds the P-11 (Pressurizer Pressure Block of Safety Injection) Setpoint, and 2)

Upon receipt of a Safety Injection test signal.

4.5.1.1.2.2 Each cold leg injection accumulator water level and pressure channel shall be demonstrated OPERABLE:

a.

At least once per 31 days by the performance of an ANALOG CHANNEL OPERATIONAL TEST, and

^

b.

At least once per 18 months by the performance of a CHANNEL CALIBRATION.

l.

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• • This surveillance need not be performed until prior to entering HOT STANDBY following the Unit I refueling.

CATAWBA - UNITS 1 & 2 3/4 5-3 Amendment No. 32 (Unit 1)

Amendment No. 23 (Unit 2)

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g 7,,-

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l l.i F

[':

EMERGENCY CORE COOLING SYSTEMS

!~

UPPER HEAD INJECTION'

[.,

l(Deleted upon.the physical disconnection of the UHI System from the Reactor Coolant System)-

c.

t I

L I

L CATAWBA - UNITS 1 & 2 3/4 5-4 Amendment No. 32 (Unit 1)

Amendment No. 23 (Unit 2)

TABLE 3.6-1 (Continued) 5 SECONDARY CONTAINMENT BYPASS LEAKAGE PATHS h>

PENETRATION

-TEST NUMBER SERVICE RELEASE LOCATION TYPE ^

l

-c

~

5 M386 Containment Air Release Auxiliary Building Type C M204 Containment' Air Addition Auxiliary Building Type C g

M316 Int. Fire Protection Header -

Auxiliary Building Type C e-1 m

-Hose Racks M337 Demineralized Water Auxiliary Building Type C M220 Instrument Air Auxiliary Building Type C M219 Station Air Auxiliary Building Type C i

R Type.C M215 Breathing Air Auxiliary Building T

M329 Reactor Coolant Pump Motor Oil Fill Auxiliary Building Type C M361 Int. Fire Protection Header -

Auxiliary Building Type C Sprinklers M119 Containment Purge Exhaust Auxiliary Building Type C gg M331 Nitrogen Supply to Cold Leg Auxiliary Building Type C

&R Accumulators

@5 ga M322 Safety Injection Test Line Auxiliary Building Type C

??

M454 UHI Test Line Auxiliary Building Type C Note 11

' l zz ww22 M328*

Component Cooling to Reactor Auxiliary Building Type C y&

Vessel Support and RCP Coolers 33

• Not applicable for Unit 1 until after the first refueling outage.

Upon capping of penetrations associated with deletion of UHI, this specification is no longer Note 1:

applicable.

aem.,

e-s,,e

e.

TABLE 3.6-2a (Continued) n 5

UNIT 1 CONTAINMENT ISOLATION VALVES MAXIMUM-c VALVE NUMBER FUNCTION ISOLATION TIME (s)-

5d 1.

Phase "A" Isolation (Continued)

KC-305B#

Excess Letdown Hx Supply Containment Isolation (Outside)

<20 ro KC-315B#

Excess letdown Hx Return Header Containment Isolation (Outside)

T20 KC-320A#

NCDT Hx Supply Hdr Containment Isolation (Outside) 720 KC-3328#

NCDT Hx Return Hdr Containment-Isolation (Inside) 720 KC-333A#

NCDT Hx Return Hdr Containment Isolation (Outside) 720 KC-429B RB Drain Header Inside Containment Isolation 710 KC-430A RB Drain Header Outside Containment Isolation 310 NB-260B Reactor Makeup Water Tank to Flush Header

$10 w1 m

NC-53B Nitrogen to Pressurizer Relief Tank #1 Containment Isolation Outside

<10 A

NC-54A Nitrogen to Pressurizer Relief Tank #1 Containment Isolation Inside 710 NC-56B RMW Pump Disch Cont Isolation 710 NC-1958 NC Pump Motor Oil Containment Isolation Outside 210 l

NC-196A NC Pump Motor Oil Containment Isolation Inside 110 NF-228A Unit 1 Air Handling Units Glycol Supply Containment Isolation Outside

<10 i

NF-2338 Unit 1 Air Handling Units Glycol Return Containment Isolation Inside 710 NF-234A Unit 1 Air Handling Units Glycol Return Containment Isolation Outside 110 l

gg

.m

&E NI-47A Accumulator N2 Supply Outside Containment Isolation

<10 22 NI-95A Test Hdr Inside Containment Isolation 710 SS NI-%B Test Hdr Outside Containment Isolation E10 NI-120B Safety Injection Pump to Accumulator Fill Line Isolation 710 zz PP NI-122B#

Hot leg Injection Check 1NI124, IN1128 Test Isolation 710.

ww NI-1548#

Hot leg Recirculation Check INI125, INI129 Test Isolation 710 I NI-255B UHI Check Valve Test Line Isolation 710' d

NI-258A UHI Check Valve Test Line Isolation 310. Note 1 EE u NI-264B UHI Check Valve Test Line Outside Containment Isolation

$10y Note 1: Upon capping of penetrations associated with deletion of UHI, these. specifications are no longer applicable.

e a-w m

r"+

..w, TABLE 3.6-2a (Continued)

~

n UNIT 1 CONTAINMENT ISOLATION VALVES

>6 MAXIMUM VALVE NUMBER

' FUNCTION ISOLATION TIME (s) b 1.

Phase "A" Isolation (Continued)

Y

{

[iNI-266A UHI Check Valve Test Line Inside Containment Isolation-

<10H Note 1 g

NI-267A UHI Check Valve Test Line Inside Containment Isolation 710 p.

l NI-153M

. Hot leg Injection Check NI156, NI159 Test Isolation 716-m i

NM-3A Pressurizer Liquid Sample Line Inside Containment Isolation

<10 NM-6A Pressurizer Steam Sample Line Inside Containment Isolation 710 NM-78 Pressurizer Sample Header Outside Containment Isolation 710 NM-22A NC Hot leg A Sample Line Inside Containment Isolation 210 NM-25A NC Hot Leg C Sample Line Inside Containment Isolation 710 NM-26B NC Hot leg Sample Hdr Outside Containment Isolation 710 w1 NM-728 NI Accumulator 1A Sample Line Inside Containment Isolation 710 NM-75B NI Accumulator IB Sample Line Inside Containment Isolation 210 t e,

4 NM-788 NI Accumulator IC Sample Line Inside Containment Isolation 710 -

NM-81B NI Accumulator ID Sample Line Inside Containment Isolation E10 NM-82A NI Accumulator Sample Hdr Outside Containment Isolation 710 NM-190M SG 1A Blowdown Line Sample Containment Isolation Inside

.710 NM-187A#

SG 1A Upper Shell Sample Containment Isolation Inside 710 NM-191B#

SG 1A Sample Hdr Containment Isolation Outside 710 NM-1978#

SG 1B Upper Shell Sample Containment Isolation Inside 710 NM-200B#

SG 1B Blowdown Line Sample Containment Isolation Inside 710

(

kk NM-201A#

SG 1B Sample Hdr Containment Isolation Outside 710 ga NM-207A8 SG IC Upper Shell Sample Containment Isolation Inside 310 l

gg NM-210M SG IC Blowdown Line Sample Containment Isolation Inside

<10 gg NM-2118#

SG IC Sample Hdr Containment Isolation Outside

<10

~

NM-2178#

SG ID Upper Shell Sample Containment Isolation Inside 710 2zPP NM-220B#

SG 1D Blowdown Line Sample Containment Isolation Inside 710 g

NM-221M SG 1D Sample Hdr Containment Isolation Outside 310 hh NV-158 Letdown Containment Isolation Outside

- <10 33 NV-89A NC Pumps Seal Return Containment Isolation Inside 710 NV-91B NC Pumps Seal Return Containment Isolation Outside 710 mg NV-314B#

Charging Line Containment Isolation Outside

{10 vv Note 1:

Upon capping of penetrations associated with deletion of UHI, these. specifications are no longer applicable.

m

~

TABLE 3.6-2b (Continued) n UNIT 2 CONTAINMENT ISOLATION VALVES 5,

2 e

MAXIMUM VALVE NUMBER FUNCTION ISOLATION TIME'(s)-

d 1.

Phase "A" Isolation ~(Continued) w e.

KC-3058#

Excess letdown Hx Supply Containment Isolation (Outside)

<20 to XC-315B#

Excess Letdown Hx Return Header Containment Isolation (Outside) 720 KC-320A#

NCOT Hx Supply Hdr Containment Isolation (Outside)

~

720 KC-3328#

NCDT Hx Return Hdr Containment Isolation (Inside) 720 KC-333A#

NCDT Hx Return Hdr Containment Isolation (Outside) 720 KC-429B RB Drain Header Inside Containment Isolation 710 KC-430A RB Drain Header Outside Containment Isolation

{10 NB-260B Reactor Makeup Water Tank to Flush Header

$10 g

I cn NC-53B Mitrogen to Pressurizer Relief Tank #1 Containment Isolation Outside

<10 l

0 NC-54A Nitrogen to Pressurizer Relief Tank #1 Containment Isolation Inside 710 l

NC-56B RMW Pump Disch Cont Isolation

{10 l

NC-195B NC Pump Motor Oil Containment Isolation Outside

$10 NC-1%A NC Pump Motor Oil. Containment Isolation Inside

$10 NF-228A Unit 2 Air Handling Units Glycol Supply Containment Isolation Outside

$10 NF-233B Unit 2 Air Handling Units Glycol Return Containment Isolation Inside

$10 NF-234A Unit 2 Air Handling Units Glycol Return Containment Isolation Outside

$10 99@@

NI-47A Accumulator N2 Supply Outside Containment Isolation

<10 NI-95A Test Hdr Inside Containment Isolation E10 NI-%B Test Hdr Outside Containment Isolation 710 NI-120B Safety Injection Pump to Accumulator Fill Line Isolation E10 EE NI-122B#

Hot leg Injection Check 2NI124, 2NI128 Test Isolation 710 i

W NI-1548#

Hot leg Recirculation Check 2NI125, 2NI129 Test Isolation.

{10

<10 MI-255B UHI Check Valve Test Line Isolation E10h' Mote 1 mm EE NI-258A UHI Check Valve Test-Line Isolation NI-264B UHI Check Valve Test Line Outside Containment Isolation 310)

Note 1: Upon capping of penetrations associated with deletion of UHI, these specifications are no longer applicable.

e y

TABLE 3.6-2b (Contir.ued) 3;'

UNIT 2 CONTAINMENT ISOLATION VALVES-Ei MAXIMUM VALVE NUMBER FUNCTION ISOLATION TIME (s) l ez Q

1.

Phase "A" Isolation (Continued) m u,

(

w NI-266A UHI Check Valve Test Line Inside Containment Isolation

<109 Note l' s

Ull-267A UHI Check Valve Test Line Inside Containment Isolation 710j l

N NI-153A#

Hot Leg Injection Check NI156, NI159 Test Isolation 710 NM-3A Pressurizer Liquid Sample Line Inside Containment Isolation

<10 NM-6A Pressurizer Steam Sample Line Inside Containment Isolation 710 NPi-7B Pressurizer Sample Header Outside Containment Isolation E10 NM-22A NC Hot Leg A Sample Line Inside Containment Isolation 710 NM-25A NC Hot Leg C Sample Line Inside Containment Isolation 710 g

NM-26B

% Hot leg Sample Hdr Outside Containment Isolation 310 NM-72B NI Accumulator 2A Sample Line Inside Containment Isolation

<10

?

NM-75B NI Accumulator 28. Sample Line Inside Cont.ainment Isolation 210 g

NM-788 NI Accumulator 2C Sample Line Inside Containment Isolation

{10 NM-81B NI Accumulator 2D Sample Line Inside Containment Isolation

<10 NM-82A NI Accumulator Sample Hdr Outside Containment Isolation 710 NM-187A#

SG 2A Upper Shell Sample Containment Isolation Inside 710 NM-190M SG 2A Blowdown Line Sample Containment Isolation Inside

{10 NM-1918#

SG 2A Sample Hdr Containment Isolation Outside

<10 NM-197B#

SG 2B Upper Shell Sample Containment Isolation Inside 710 NM-200B#

SG 2B Blowdown Line Sample Containment Isolation Inside

{10

[,

NM-201M SG 2B Sample Hdr Containment Isolation Outside

$10 g

gg NM-207M SG 2C Upper Shell Sample Containment Isolation Inside

$10 sa NM-210M SG 2C Blowdown Line Sample Containment Isolation Inside

<10 NM-211B#

SG 2C Sample Hdr Containment Isolation Outside

' 710

((

NM-2178#

SG 2D Upper Shell Sample Containment Isolation Inside 310 gp NM-220B#

SG 2D Blowdown Line Sample Containment Isolation Inside

<10 NM-221M SG 2D Sample Hdr Containment Isolation Outside

<10 EE NV-15B Letdown Containment Isolation outside

<10 EN NV-89A NC Pumps Seal Return Containment Isolation Inside

.210 m9 NV-91B NC Pumps Seal keturn Containment Isolation Outside 710 NV-314B#

Charging Line Containment Isolation Outside

{10 Note 1: Upon capping of penetrations associated with deletion of UNI, these specifications are no longer applicable.

O B

j TABLE 3.8-1A (Continued)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES

[

DEVICE NUMBER & LOCATION SYSTEM POWERED 2.

600 VAC MCC (Continued) 1EMXD-F02C

~

Primary Bkr Pressurizer Power-Operated Relief Backup Fuse 1s01 Viv 1NC31B 1EMXD-F05A Primary Bkr Pressurizer Power-Operated Relief Backup Fuse 1s01 Viv 1NC35B l

IEMXD-F05B Primary Bkr Rx Bldg Drain Hdr Inside Cont Backup Fuse 1501 Viv IKC429B IEMXD-FOSC Primary Bkr NCDT Hv Cing Water Return Inside Backup Fuse 1501 Viv IKC3328

^

1EMXD-F06A Primary Bkr NC Pump 1B Thermal Barrier Outlet Backup Fuse Isol Viv 1KC364B IEMXD-F06B Primary Bkr NC Pumps Rtn Hdr Inside Cont Backup Fuse 1501 Viv 1KC424B IEMXK-F01A Primary Bkr UHI Check Viv Test Line Inside1 (o

Note 1 Backup Fuse Cont Isol Viv 1N1266A j

IEMXK-F01B Primary Bkr Upper Cont Vent Units Return Backup Fuse Cont Isol Viv 1RN429A 1EMXK-F01C Primary Bkr Backup Na to PORV INC34A From Backup Fuse Accum Tnk 1A Viv 1NI43BA 1EMXK-F02A Primary Bkr NC Pump 1A Thermal Barrier Backup Fuse Outlet Isol Viv 1KC394A 1EMXK-F02B Primary Bkr Lower Cont Vent Units Return Backup Fuse Cont Isol Viv 1RN4B4A Note 1:

Upon removal of cable from power source associated with the deletion of UHI, this specification is no longer applicable.

CATAWBA - UNITS 1 & 2 3/4 B-23 Amendment No. 3XUnit 1)

Amendment No. 2XUnit 2)

~

1 4

(o i

)

TABLE 3.B-1A (Continued)

+

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER & LOCATION SYSTEM POWERED 2.

600 VAC MCC (Continued) 1EMXK-F02C Primary Bkr NV Supply to Pressurizer Viv Backup Fuse INV037A IEMXK F03A Primary Bkr S/G C Blewdown Line Sample Backup Fuse Inside Cont Isol Viv INM210A 1EMXK-F04A Primary Bkr S/G A Upper Shell Sample Inside Backup Fitse Cont Isol Viv INM187A 1EMXK-F04B Primary Bkr S/G A Blowdown t.ine Sample Backup Fuse Inside Cont 1501 Viv INM190A 1EMXK-F04C Primary Bkr S/G C Upper Shell Sample Backup Fuse Inside Cont Isol Viv INM207A IEMXK-F06A Primary Bkr Hydrogen Skimmer Fan 1A Backup Fuse Inlet Viv IVX1A 1EMXK-F07C Primary Bkr Electric Hydrogen Recombiner Backup Fuse Power Supply Panel 1A 1EMXK-F09A Primary Bkr Accumulator 1A Discharge Isol Backup Fuse Viv 1NI54A

[1EMXK-F09B 9

f Primary Bkr UHI Check Viv Test Line Inside b Note 1

( Backup Fuse Cont Isol V1v 1N1267A g

IEMXK-F090 Primary Bkr NC Pump Oil Fill Header Backup Fuse Cont Isol V1v 1NC196A Note 1:

Upon removal of cable from power source associated with the deletion of UHI, this specification is no longer applicable.

I CATAWBA - UNITS 1 & 2 3/4 B-24 Amendment No. 3 Unit 1)

Amendment No.2 Unit 2) l

TABLE 3.8-1B (Continued)

UNIT 2 CONTAINMENT PENETRATION CON' UCTOR OVERCURRENT PROTECTIVE DEVICES D

DEVICE NUMBER & LOCATION SYSTEM POWERED 2.

600 VAC MCC (Continued)

)

2EMXC-F05A Primary Bkr NCDT Vent Inside Cont 150)

Backup Fuse Viv 2WL450A 2EMXC-F05B Primary Bkr Cont Sump Pumps Discharge Inside Backup Tuse Cont Isol Viv 2WLB25A 2EMXC-F05C Primary Bkr Vent Unit Cond Drn Tank

~

Backup Fuse Outside Cont Isol Viv 2WL867A 2EMXC-F06A Primary Bkr NCDT Pumps Disch Inside Cont Isol Back > Fuse Viv 2WLB05A 2EMXC-F07B

(

Primary Bkr Cont H Purge Outlet Cont Isol Backup Fuse Viv 2V,17A Y

2EMXD-F01A Primary Bkr ND Pump 2A Suction From NC Backup Fuse Loop B Viv 2ND1B 2EMXD-F01B Primary Bkr Accumulator 2B Discharge t

Backup Fuse 1501 Viv 2N!65B 2EMXD F010 Primary Bkr NI Pump A to Hot Leg Check Backup Fuse Viv Test 1s01 Viv 2N1122B 2EMXD-F02A Primary Skr ND Pump 2B Suction from NC Backup Fuse Loop C Viv 2ND36B 2EMXD-F02B l

Primary Bkr ND to Hot Legs Chk 2N1125, 2N1129 i

Backup Fuse Test 15o1 Viv 2NI154B, l

CATAWBA - UNITS 1 & 2 3/4 8-45

i I

TABLE 3.8-1B (Continued)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES

[

DEVICE NUMBER & LOCATION SYSTEM POWERED r

2.

600 VAC MCC (Continued) 2EMXD-F02C Primary Bkr Pressurizer Power-Operated Relief Backup Fuse Isol Viv 2NC31B 2EMXD-F05A Primary Bkr Pressurizer Power-Operated Relief Backup Fuse Isol Viv 2NC35B 2EMXD-F05B Primary Bkr Rx Bldg Drain Hdr Inside Cont Backup Fuse Isol Viv 2KC429B 2EMXD-F05C Primary Bkr NCDT Hx Cing Water Return Inside Backup Fuse Isol Viv 2KC332B 1

2EMXD-F06A Primary Bkr NC Pump 2B Thermal Barrier Outlet Backup Fuse Isol Viv 2KC364B i

2EMXD-F06B Primary Bkr NC Pumps Rtn Hdr Inside Cont Backup Fuse 1501 Viv 2KC424B 2EMXK-F01A 3

Note 1 Primary Bkr UHI Check V1v Test Line Inside

%{

Backup Fuse Cont Isol Viv 2NI266A J

l 2EMXK-F01B Primary Bkr Upper Cont Vent Units Return Backup Fuse Cont Isol Viv 2RN429A 2EMXK-F01C Primary Bkr Backup N to PORV 2NC34A From 2

Backup Fuse Accum Tnk 2A Viv 2NI438A 2EMXK-F02A Frimary Bkr NC Pump 2A Thermal Barrier Backup Fuse Outlet Isol Viv 2KC394A 2EMXK-F02B Primary Bkr Lower Cont Vent Units Return Backup Fuse Cont Isol Viv 2RN484A Note 1:

Upon removal of cable'from power source associated with the deletion of UHI, this specification is no longer applicable.

CATAWBA - UNITS 1 & 2 3/4 8-46 Amendment No.32(Unit 1)

Amendment No.23(Unit 2)

^'

o-TABLE 3.8-1B (Continued)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER & LOCATION SYSTEM POWERED 2.

600 VAC MCC (Continued) t 2EMXK-F02C Primary Bkr NV Supply to Pressurizer Viv Backup Fuse 2NV037A 2EMXK-F03A Primary Bkr S/G C Blowdown Line Sample Backup Fuse Inside Cont Isol Viv 2NM210A 2EMXK-F04 A Primary Bkr S/G A Upper Shell Sample Inside Backup Fuse Cont Isol V1v 2NM187A 2EMXK-F04B Primary Bkr S/G A Blowdown Line Sample Backup Fuse Inside Cont Isol Viv 2NM190A 2EMxK-F04C Primary Bkr S/G C Upper Shell Sample Backup Fuse Inside Cont 1501 Viv 2NM207A 2EMXK-F06A Primary Bkr Hydrogen Skimmer Fan 2A Backup Fuse Inlet Viv 2VX1A 2EMXK-F07C Primary Bkr Electric Hydrogen Recombiner Backup Fuse Power Supply Panel 2A 2EMXK-F09A Primary Bkr Accumulator 2A Discharge Isol Backup Fuse Viv 2NI54A

1. 2EMXK-F09B i

Note 1 e

Primary Bkr UHI Check Viv Test Line Inside - -

( Backup Fuse Cont Isol Viv 2NI267A j

2EMXK-F09C Primary Bkr NC Pump 011 Fill Header Backup Fuse Cont Isol Viv 2NC196A Note 1:

Upon removal of cable from power source associated with the deletion of UHI, this specification is no longer applicable.

CATAWBA - UNITS 1 & 2 3/4 8-47 Amendment No.32(Unit 1)

Amendment No.23(Unit 2)

1 TABLE 3.B-1B (Continued)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES M-DEVICE NUMBER & LOCATION SYSTEM POWERED 2.

600 VAC MCC (Continued) t 2EMXK-F10 A Primary Bkr Containment Air Return Damper Backup Fuse 2 ARF D-2 2EMXK-F10B Primary Bkr VQ Fans Suction From Containment Backup Fuse Isol Viv 2VQ2A 4

2EMXK-F10C Primary Bkr Cont Air Addition Containment Backup Fuse Isol Viv 2VQ16A t

2EMXK-F11A Primar Bkr Containment Air Return Fan Back se Motor 2A 2EMXK-F11B Primary Bkr Hydrogen Skimmer Fan Motor 2A Backup Fuse 2EMXL-F01B Primary Bkr Trn B Alternate Power to ND Backup Fuse Letdn Viv 2ND37A 2EMXL-F01C Primary Bkr NI Accum D Sample Line Inside Backup Fuse Cont 1501 Viv 2NM81B 2EMXL-F02A Primary Bkr NC Pump 20 Thermal Barrier Backup Fuse Outlet Isol Viv 2KC433B 2EMXL-F02B Primary Bkr Air Handling units Glycol Return Backup Fuse Cont Isol Viv 2NF233B 2EMXL-F02C Primary Bkr NI Accum C Sample Line Inside Backup Fuse Cont Isol Viv 2NM78B.-

2EMXL-F03A Primary Bkr S/G D Blowdown Sample Line Inside Backup Fuse Cont 1501 Viv 2NM220B CATAWBA - UNITS 1 & 2 3/4 B-48

-e 3/4.5 EMERGENCY CORE COOLING SYSTEMS t

BASES 3/4.5.1 ACCUMULATORS The OPERABILITY of each Reactor Coolant System accumulator ensures that a suf ficient volume of borated water will be immediately forced into the reactor core through each of the cold legs from the cold leg injection t

accumulators and directly into the reactor vessel from the upper head injection accumulators in the event the Reactor Coolant System pressure falls below the pressure of the accumulators.

This initial surge of water into the core provides the initial cooling mechanism during large pipe ruptures, t

The limit:; on accumulator volume, boron concentration and pressure ensure that the assumptions used for accumulator injection in the safety analysis are met.

The allowed down time for the accumulators are variable based upon boron concentration to ensure that the reactor is shutdown following a LOCA and that any problems are corrected in a timely manner.

Suberiticality is assured when boron concentration is above 1500 ppm, so additional down time is allowed when concentration is above 1500 ppm.

A concentration of less than 1900 ppm in any single accumulator or as a volume weighted average may be indicative of a pro-blem, such as valve leakage, but since reactor shutdown is sssured, additional time is allowed to restore boron concentration in the accumulators.

The accumulator power operated isolation valves are considered to be

" operating bypasses" in the context of IEEE Std. 279-1971, which requires that bypasses of a protective function be removed automatically whenever permissive conditions are not met.

In addition, as these accumulator isolation valves fail to meet single failure criteria, removal of power to the valves is required.

The limits for operation with an accumulator inoperable for any reason except an isolation valve closed minimizes the time exposure of the plant to a LOCA event occurring concurrent with failure of an additional accumulator which may result in unacceptable peak cladding temperatures.

If a closed l

isolation valve cannot be immediately opened, the full capability of one accumulator is not available and prompt action is required tn place the reactor in a mode where this capability is not required.

The original licensing basis for the Catawba Nuclear Station assumes both the UHI System and Cold Leg Accumulators function to mitigate postulated accidents.

Subsequent analyses have demonstrated that the UHI System is not required provided minor changes to the Cold Leg Accumulator parameters and discharge paths are implemented. Accordingly, Specification 3/4.5.1 has been modified to address two possible plant configurations:

(1) UHI Operable (Original plant configuration)

(2) UHI Disconnected (VHI penetrations to the Reactor Vessel are cut and capped, Cold Leg Accumulator level and cover pres-sure changed, Cold Leg Accumulator flow restricting orifice replaced)

I CATAWBA - UNITS 1 & 2 B 3/4 5-1 Amendment No. 32 (Unit 1)

Amendment No. 23 (Unit 2) l

l EMERGENCY CORE COOLING SYSTEMS BASES 3/4.5.2 and 3/4.5.3 ECCS SUBSYSTEMS The OPERABILITY of two independent ECCS subsystems ensures that sufficient emergency core cooling capability will be available in the event of a LOCA assuming the loss of one subsystem through any single failure consideration.

Either subsystem operating in conjunction with the accumulators is capable of supplying sufficient core cooling to limit the peak cladding temperatures within acceptable limits for all postulated break sizes ranging from the double ended break of the largest cold leg pipe downward.

In addition, each ECCS subsystem provides long term core cooling capability in the recirculation mode during the accident recovery period.

With the coolant temperature below 350'F, one OPERABLE ECCS subsystem is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the limited core cooling requirements.

The limitation for a maximum of one centrifugal charging pump and one Safety Injection pump to be OPERABLE and the Surveillance Requirement to verify all charging pumps and Safety Injection pumps except the required OPERABLE centrifugal charging pump to be inoperable below 285'F provides assurance that a mass addition pressure transient can be relieved by the operation of a single PORV.

The Surveillance Requirements provided to ensure OPERABILITY of each component ensures that at a minimum, the assumptions used in the safety analyses are met and that subsystem OPERABILITY is maintained.

Surveillance Requirements for throttle valve position stops and flow balance testing provide assurance that proper ECCS flows will be maintained in the event of a LOCA.

Maintenance of proper flow resistance and pressure drop in the piping system to each injection point is necessary to:

(1) prevent total pump flow from exceeding runout conditions when the system is in its minimum resistance l

configuration, (2) provide the proper flow split between injection points in accordance with the assumptions used in the ECCS-LOCA analyses, and (3) provide an acceptable level of total ECCS flow to all injection points equal to or above that assumed in the ECCS-LOCA analyses.

3/4.5.4 REFUELING WATER STORAGE TANK The OPERABILITY of the refueling water storage tank as part of the ECCS ensures that a sufficient supply of borated water is available for injection by the ECCS in the event of a LOCA.

The limits on minimum volume and boron

~

concentration ensure that:

(1) sufficient water is available within containment to permit recirculation cooling flow to the core, and (2) the reactor will remain subtritical in the cold condition following mixing of the refueling water storage tank and the Reactor Coolant System water volumes with all control rods inserted except for the most reactive control assembly.

These assumptions are consistent with the LOCA analyses.

l CATAWBA - UNITS 1 & 2 B 3/4 5-2 Amendment No. 32 (Unit 1)

Amendment No,23 (Unit 2)

e < o 4

i EMERGENCY CORE COOLING SYSTEMS j

BASES REFUELING WATER STORAGE TANK (Continued)

The contained water volume limit includes an allowance for water not usable because of tank discharge line location or other physical characteristics.

The limits on contained water volume and boron concentration of the refueling water storage tank also ensure a pH value of between 8.0 and 9.0 for the solution recirculated within containment after a LOCA. This pH band mini-mizes the evolution of iodine and minimizes the effect of chloride and caustic stress corrosion on mechanical systems and components.

r CATAWBA - UNITS 1 & 2 B 3/4 5-3 Amendment No. 32(Unit 1)

Amendment No. 23(Unit 2)

.-.