Text

Amends 59 & 47 to Licenses NPF-76 & NPF-80,respectively, Change AOTs & STIs for 22 Tss,As Result of Plant PSA
	ML20067D175
Person / Time
Site:	South Texas
Issue date:	02/17/1994
From:	Black S; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20067D177	List: ML20067D175; ML20067D178; ML20067D184;
References
	NUDOCS 9403080077
	Download: ML20067D175 (41)
	v • d • e

'

Rp'<sm'c, l

j

[ kf

( Q [,j c

UNITED STATES l

NUCLEAR REGULATORY COMMISSION 5

e WASHINGTON, D.C. 20$55-0001 HOUSTON LIGHTING & POWER COMPANY CITY PUBLIC SERVICE BOARD OF SAN ANTONIO CENTRAL POWER AND LIGHT COMPANY CITY OF AUSTIN. TEXAS DOCKET N0. 50-498 SOUTH TEXAS PROJECT. UNIT 1 AMEN 0 MENT TO FACILITY OPERATING LICENSE Amendment No. 59 License No. NPF-76 1.

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

A.

The application for amendment by Houston Lighting & Power Company *

(HL&P) acting on behalf of itself and for the City Public Service Board of San Antonio (CPS), Central Power and Light Company (CPL),

and City of Austin, Texas (C0A) (the licensees) dated February 1, 1990, as supplemented by letters dated November 27, 1990, June 5, 1991, November 3, 1992, November 11, 1992, August 16, 1993, October 22, 1993, November 5, 1993 (two letters), and November 29, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B.

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

There is reasonable assurance:

(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.

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

Houston Lighting & Power Company is authorized to act for the City Public Service Board of San Antonio, Central Power and Light Company and City of Austin, Texas and has exclusive responsibility and control over the physical construction, operation and maintenance of the facility.

94030aoo77 940217 PDR ADOCK 05000490 P

PDR

9 '

E.

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

4 2.

Accordingly, the license is amended by 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-76 is hereby amended to read as follows:

2.

Technical Soecifications The Technical Specifications contained in Appendix A, as revised through Amendment No.

59, and the Environmental Protection Plan contained in' Appendix B, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical-Specifications and the Environmental Protection Plan.

3.

The license amendment is effective as of its date of issuance to be implemented within 45 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION

(

d%wt, ACd Suzanne'. Black, Director Project Directorate IV-2 Division of Reactor Projects III/IV/V Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

February 17, 1994 I

je %

f.,

.\\

E UNITED STATES i g;~ V,,7 j

NUCLEAR REGULATORY COMMISSION g-WASHINGTON, D C. 20$55-0001 HOUSTON LIGHTING & POWER COMPANY CITY PUBLIC SERVICE BOARD OF SAN ANTONIO CENTRAL POWER AND LIGHT COMPVH CITY OF AVSTIN. TEXA$

DOCKET NO 50-499 l

SOUTH TEXAS PROJECT. UNIT il AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 47 License No. NPF-80 1.

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

A.

The application for amendment by Houston Lighting & Power Company *

(HL&P) acting on behalf of itself and for the City Public Service Board of San Antonio (CPS), Central Power and Light Company (CPL),

and City of Austin, Texas (C0A) (the licensees) dated February 1, 1990, as supplemented by letters dated Novemoer 27, 1990, June 5, 1991, November 3, 1992, November 11, 1992, August 16, 1993,

)

October 22, 1993, November 5, 1993 (two letters), and November 29, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, as amended, 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; 0.

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

Houston Lighting & Power Company is authorized to act for the City Public Service Board of San Antonio, Central Power and Light Company and City of Austin, Texas and has exclusive responsibility and control over the physical cnnstruction, operation and maintenance of the facility.

e

, E.

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

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment and Paragraph 2.C.(2) of Facility Operating License No. NPF-80 is hereby amended to read as follows:

2.

Technical Soccifications The~ Technical Specifications contained in Appendix A,'as revised through Amendment No.

47, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

The license amendment is effective as of its date of issuance to be implemented within 45 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION

(

wg.t C

Suzanne Black, Director Project Directorate IV-2 Division of Reactor Projects Ill/IV/V Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

February 17, 1994 l

r ATTACHMENT TO LICENSE AMENDMENT NOS. 59 AND 47 FACILITY OPERATING llCENSE N05. NPF-76 AND NPF-[LQ DOCKET NOS. 50-498 AND 50-499 Replace the following pages of the Appendix A Technical Specifications with the attached 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.

l REMOVE INSERT 3/4 1-12 3/4 1-12 3/4 3-13 3/4 3-13 3/4 3-14 3/4 3-14 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 3-48 3/4 3-48 3/4 3-49 3/4 3-49 3/4 4-8 3/4 4-8 3/4 5-1 3/4 5-1 3/4 5-3 3/4 5-3 3/4 5-11 3/4 5-11 3/4 6-14 3/4 6-14 3/4 6-16 3/4 6-16 3/4 6-17 3/4 6-17 3/4 7-1 3/4 7-1 3/4 7-12 3/4 7-12 3/4 7-16 3/4 7-16 3/4 7-31 3/4 7-31

l r

J REACTIVITY CONTROL SYSTEMS CHARGING PUMPS - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.1.2.3 One charging pump in the boron injection flow path required by Specification 3.1.2.1 shall be OPERABLE and capable of being powered from an OPERABLE emergency power source.

APPLICABILITY:

H3 DES 4**, 5, and 6.

ACTION:

With no charging pumo OPERABLE or capable of being powered from an OPERABLE emergency power source, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.

SURVEILLANCE REQUIREMENTS 4.1.2.3.1 The above required charging pump shall be demonstrated OPERABLE by verifying, on recirculation flow, that a differential pressure across the pump of greater than or equal to 2300 psid is developed when tested pursuant to Specification 4.0.5.

4.1.2.3.2 All charging pumps, excluding the above required OPERABLE pump, shall be demonstrated inoperable

at least once per 31 days, except when the reactor vessel head is removed, by verifying that the motor circuit breakers are secured in the open position.

An inoperable pump may be energized for testing provided the discharge of the pump has been isolated from the RCS by a closed isolation valve with power removed from the valve operator, or by a manual isolation valve secured in the closed position.

- The provisions of Specification 3.0.4 and 4.0.4 are not applicable for entry into MODE 4 from MODE 3 for the charging pumps declared OPERABLE pursuant to Specification 4.1.2.4 provided that a maximum of one charging pump is OPERABLE within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 4 from MODE 3 or prior to the temperature '

of one or more of the RCS cold legs decreasing below 325'F, whichever comes first.

SOUTH TEXAS - UNITS 1 & 2 3/4111

3 REACTIVITY CONTROL SYSTEMS CHARGING PUMPS - OPERATING llMITING CONDITION FOR OPERATION 3.1.2.4 At least two charging pumps shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3

ACTION:

With only one charging pump OPERABLE, restore at least two charging pumps to OPERABLE status within 7 days or be in at least HOT STANDBY and borated to a SHUTDOWN MARGIN equivalent to at least the limit as shown in Figure 3.1-2 at 200*F within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore at least two charging pumps to OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVElllANCE RE0VIREMENTS 4.1.2.4 At least two charging pumps shall be demonstrated OPERABLE by verifying, on recirculation flow, that a differential pressure across each pump of greater than or equal to 2300 psid is developed when tested pursuant to Specification 4.0.5.

The provisions of Specification 3.0.4 and 4.0.4 are not applicable for entry into MODE 3 for the charging pumps declared inoperable pursuant to Specification 4.1.2.3.2 provided that the charging pump is restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or prior to the temperature of one or more of the RCS cold legs exceeding 375'F, whichever comes first.

SOUTH TEXAS - UNITS 1 & 2 3/4 1-12 Unit 1 - Amendment No. 59 Unit 2 - Amendment No. 47

l i

-~

j TABLE 4.3-1 (Continued)

'l 8y REACTOR TRIP SYSTEM INSTRUE NTATION SURVEILLANCE REQUIREMENTS

~

M i

5 TRIP ANALOG ACTUATING MODES FOR CHANNEL DEVICE WHICH CHANNEL CHAf0fEL OPERATIONAL OPERATIONAL ACTdATION SURVEILLANCE E FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST

-LOGIC TEST IS REQUIRED' t

19.

Reactor Trip System Interlocks

[

a.

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

R(4)

R N.A.

N.A.

2**

b.

Low Power Reactor i

Trips Block, P-7 N.A.

R(4)

R N. A.

N.A.

1 c.

Power Range Neutron

{

g Flux, P-8 N.A.

R(4)

R N.A.

N. A.

1 y

d.

Power Range Neutron g

Flux, P-9 N.A.

R(4)

.R -

N. A.

1-6 t

e.

Power Range l

Neutron Flux, P-10 N.A.

R(4)

R N.A.

N.A.

1, 2 f.

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

R R

N.A.

1 4

20.

Reactor Trip Breaker N. A.

N.A.

Q(7,11)

N.A.

1,2,3*,4*,5*h CC 11 21. Automatic Trip and Interlock N. A.

M. A.

N.A.

Q(7) 1,2,3",4*,5*ll l

Logic m

t 22.

Reactor Trip Bypass Breaker N.A.

M.A.

N.A.

Q(15),R(16)

N.A.

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

i YE D D Q. C2.

BB on i

DkS

I T

l TABLE 4.3-1 (Continued) l JABLE NOTATIONS

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

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

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

(1)

If not performed in previous 31 days.

(2) Comparison of calorimetric to excore power indication above 15% of RATED THERMAL POWER.

Adjust excore channel gains consistent with calorimetric 1

power if absolute difference is greater than 2%.

The provisions of Specification 4.0.4 are not applicable to 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 provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1.

For the purpose of this surveillance requirement, monthly shall mean at least once per 31 EFPD.

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

(5) Detector plateau curves shall be obtained and evaluated.

If a low noise l

preamplifier is used with the Source Range Detector, no plateau curve is obtained.

Instead, with the high voltage setting varied as recommended by the manufacturer, an initial discriminator bias curve shall be l

measured for each detector. Subsequent discriminator bias curves shall be obtained, evaluated and compared to the initial curves.

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.

For the purpose of this surveillance requirement, quarterly shall mean at least once per 92 EFPD.

1 (7)

Each train shall be tested at least every 92 days on a STAGGERED TEST l

BASIS.

(8)

(Not Used)

(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 l

for existing plant conditions by observation of the permissive annunciator window.

i SOUTH TEXAS - UNITS 1&2 3/4 3-14 Unit 1 - Amendment No. 4,M,W,59 Unit 2 - Amendment No. 7,47

=

l 9

r j

TABLE 3.3-5 (Continued) l i

(This table number not used) l l

l l

l 1

l l

l SOUTH TEXAS - UNITS 1 & 2 3/4 3-41 Unit 1 - Amendment No. 50 l

Unit 2 - Amendment No. 39 l-l l

TABLE 4.3-7

o S

ENGINEERED SAFETY FEAIURES ACTUATION SYSTEM INSTRUNENTATION 50RvillLANCE REQUIMENLNIS "n

r DIGITAL OR TRIP h

MODES ANALOG ACTUATING CHANNEL DEVICE MASTER SLAVE FOR WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE c

CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST 15 REQUIRED g FLMCTIONAL UNIT

1. Safety Injection (Reactor Trip, Feedwater Isolation, u

Control Room Emergency Ventilation, Start Standby Olesel Generators, Reactor Containment Fan Coolers, and Essentini Cooling Water) o

[

a. Manual Inftiation N.A.

N.A.

R N.A.

M.A.

N.A.

1,2,3,4 s

~

b. Automatic Actuation M.A.

N.A.

Q(1)

N.A.

M.A.

1, 2, 3, 4 l

Logic

c. Actuat1on Relays N.A.

M.A.

N.A.

N. A.

N.A.

Q(6)

Q(4.5) I, 2, 3, 4 l

d. Containment Pressure-S R

Q N.A.

M.A.

N.A.

1,2,3,4 l

High-1

e. Pressurizer Pressure-S R

Q M.A.

M.A.

N.A.

1,2,3 l

~~

l f

hf

f. Compensated Steam Line S R

Q N.A.

N.A.

M.A.

1,2,3

[

l Pressure-Low g

E E.

I i

l

.. m m _.... _ _. -. -

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

c i

IABLE 4.3-2 (Continued) y, 8

5*

ENGINEERED SAILTY FEATURES ACTUATION SYSTEM INSIRUMENTATION f

SURV[11 LANCE REQUIREMENTS m

x

?

DIGIIAL OR TRIP ANALOG ACTUATING MODES c

CHANNEL DEVICE MASTER SLAVE FOR WHICH 2'i CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE i

d FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED i

2. Containment Spray e.

~

a. Manual Initiation N.A.

N.A.

R N.A.

N.A.

1, 2, 3, 4 l

b. Automatic Actuation N.A.

N.A.

Q(1)

N.A.

1, 2, 3, 4 l

Logic

c. Actuation Re"Tays N.A.

N.A.

M.A.

N. A.

N.A.

Q(6)

Q 1, 2, 3, 4 l

i

d. Containment Pressure-S R

O N.A.

N.A.

1, 2, 3 I

^'

j High-3

3. Containment Isolation

a. Phase "A" Isolation l

1) Manual Initiation N.A.

N.A.

~N.A.

R N.A.

N.A.

N.A 1, 2, 3, 4

(

2) Automatic Actuation N.A.

N.A.

g(1)

N.A.

M.A.

1, 2, 3, 4

];

cc

3. 3.

Logic on

"~

i

3) Actuation Relays N.A.

N.A.

Q(6)

Q(4)

I, 2, 3, 4 I

l F 3"

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

i E$

&R

b. Containment Ventilation Isolation

~

EE j

1) Automatic Actuation N.A.

N.A.

Q(I)

N.A.

M.A.

1, 2, 3, 4

. E E.

lo9ic eg

2) Actuation Relays N.A.

N.A.

Q(6)

Q 1, 2, 3, 4 i

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION w

5URVEILLANCE REQUIREMENTS z

DIGITAL OR TRIP M

MODES ANALOG ACTUATING CHANNEL DEVICE MASTER SLAVE FOR milch 5

CHANNEL CHANNEL CilANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE E

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST 15 REQUIRED

3. Containment Isolation (ContinW')1?em 1. above for all Safety Injection Surveillance Requirements.

[

3) Safety Injection S-Radioactivity-High 5

R Q

N.A.

1,2,3,4,5*,6*

l

4) RCB Purge

~

See Item 2. above for Containment Spray manual initiation Surveillance

5) Containment Spray -

Manual Initiation Requirements.

See Item 3.a. above for Phase "A" Isolation manual initiation

6) Phase "A" Isolation-y Manual Init,iation Surveillance Requirements.

[

c. Phase "B" Isolation

1) Automatic Actuation N.A.

N.A.

Q(1)

N.A.

1,2,3,4 l

Logic

2) Actuation Relays N.A.

N.A.

Q(6)

Q 1,2,3,4 l

N.A.

1,2,3 l

S

3) Containment 5

R Q

CC Pressure--High-3 See Item 2. above for Containment Spray manuai initiation Surveillance Requirements.

[

4) Containment Spray-Manual Initiation EE gg

d. RCP Seal Injection Isolation g

S5

1) Automatic Actuation N.A N.A.

N.A.

Q Q

1,2,3,4 om gg Logic and Actuation Relays

2) Charging Header 5

R Q

N.A.

H.A.

N.A.

H.A.

1,2,3,4 Of Pressure - Low See Item 3.a. above for Phase "A" surveillance requirements.

Coincident with Phase "A" Isolation

.. ~.

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

TABLE 4.3-2 (Continued) v.8M ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION w

SURVEILLANCE REQUIREMENTS E

DIGITAL OR TRIP ANALOG ACTUATING M00[5 c-CHANNEL DEVICE MASTER SLAVE FOR WHICH 5

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION

. RELAY RELAY SURVEILLANCE d

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

4. Steam Line Isolation m

L

a. Manual Initiation N.A.

N.A.

R N.A.

N.A.

1, 2, 3

b. Automatic Actuation N.A.

N.A N.A N.A.

Q(1)

Q(6)

Q 1,2,3 ll Logic and Actuation t

Relays w1

c. Steam Line Pre'ssure-S R

Q H.A.

N.A.

3 l

Negative Rate-High w.$

d. Containment Pressure -

S R

Q N.A.

N.A.

1, 2, 3 l'

High-2

e. Compensated Steam Line 5

-R Q

N.A.

1,2,3 l

Pressure-Low EE 2 %

5. Turbine Trip and Feedwater Isolation me

, e

a. Automatic Actuation N.A.

N.A.

Q(1)

.Q(6)

Q(4) 1, 2, 3 l

kk Logic and Actuation R&

Relays R$

SE

b. Steam Generator Water S

R Q

N.A.

1, 2, 3

['

z2 Level-High-High (P-14) l PP w

c. Deleted w.

d. Deleted

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

i

TABLE 4.3-2 (Contiaued)

ENGINEERED SAFETY FEAIURES ACIUATION SYSIEM INSTRUMENTATION o3 SURVEILLANCE REQUIREiiENTS 1

DIGITAL OR TRIP

-4 MODES E

ANALOG ACTUATING M

CllANNEL DEVICE MASTER SLAVE FOR WHICil CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE g FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED 3

5. Turbine Trip and Feedwater Isolation (Continued) 5 R

Q N.A.

N.A.

1, 2, 3 l

y

f. T,yg-Low Coincident with Reactor Trip (P-4)

(Feedwater Isolation Only)

6. Auxiliary Feedwater

a. Manual Initiation N.A.

N.A.

N. A..

R N.A.

N.A.

1, 2, 3 y

b. Automatic Actuation N.A.

N.A.

Q(1)

N.A.

1, 2, 3 l

logic

c. Actuation Relays N.A.

N.A.

H.A.

N.A.

Q(6)

Q

'i,2,3 l

d. Steam Generator Water 5

R Q

N. A.

N.A.

N.A N.A 1, 2, 3 l

Level--Low-Low See Item 1. above for all Safety Injection Surveillance Requirements.

e. Safety Injection See Item 8. below for all Loss of Power Surveillance Requirements.

f. Loss of Power CC

3. 3.

7.

Automatic Switchover to Containment Sump

a. Automatic Actuation N.A.

N.A.

Q(6)

Q 1, 2, 3, 4 l

~~

EF Logic and Actuation

((

Relays 88

b. RWST Level--Low-Low S

R Q

N. A.

N.A.

N.A 1, 2, 3, 4

[

%A Coincident With:

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

22PP Safety Injection

Y TABLE 4.3-2 (Continued) v, 8y ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION a

SURVEILLANCE REQUIREMENTS 0

3; DIGITAL OR-TRIP ANALOG ACTUATING MODES c

CHANNEL DEVICE MASTER SLAVE FOR WHICH i'i CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION. RELAY RELAY SURVEILLANCE d

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

8. Loss of Power m

a. 4.16 kV ESF Bus N.A.

R N.A Q

N.A.

N.' A.

N.A.

1, 2,--3, 4 -l Undervoltage (Loss of Voltage)

b. 4.16 kV ESF Bus N.A.

R N.A.

Q N.A.

N.A.

1,2,3,4 l

w2 Undervoltage (' Tolerable Degraded Voltage w

f Coincident with SI)

c. 4.16 kV ESF Bus N.A.

R N.A.

Q N.A.

N.A.

1,2,3,4 l

Undervoltage (Sustained Degraded Voltage)

CC

3.

9. Engineered Safety Features Actuation L

System Interlocks

.i FF

a. Pressurizer N.A.

R Q

N.A.

1,2,3 I

@E Pressure, P-11 l

@ o$

b. Low-Low Tavg, P-12 N.A.

R Q

N.A.

1,2,3 l

o

&E

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

N.A N. A.

R N.A.

N.A.

1, 2, 3 4

07 10. Control Room Ventilation 1

m i

a. Manual Initiation N.A.

N.A.

R N.A.

H. A.

N.A.

All 1

l 1

TABLE 4.3-2 (Continued)

%5 ENGINEEREO SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION

[

SURVEILLANCE REQUIRENENTS m

5 DIGITAL TRIP ANALOG ACTUATING NODES CHANNEL DEVICE MASTER SLAVE FOR WHICH E

CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE y

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

[ 10. Control Room Ventilation (Continued)

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

c. Automatic Actuation N. A.

N.A.

Q(6)

N.A.

All l

Logic and Actuation Relays

,x

d. Control Room Intake Air S R

Q N.A.

N.A.

All l

^

"A Radioactivity-High m

e. Loss of Power See Items 8. above for all Loss of Power Surveillance Requirements.

11. FHB HVAC t

a. Nanual Initiation N.A.

N.A.

R N.A.

N.A.

1, 2, 3, 4, or with ff irradiated fuel in the spent-fuel pool l

g l

a

b. Automatic Actuation N.A.

N.A.

Q(6)

N.A.

1, 2, 3, 4, l 4

mm or with k@

Logic and Actuation irradiated j

SS Relays fuel in the spent fuel zz

??

pool l

OE h

l x

l

T a

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

-4O E

DIGITAL OR TRIP ANALOG ACTUATING MODES i

CHANNEL DEVICE MASTER SLAVE FOR WHICH g

y CHANNEL CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE m

FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST

~ TEST IS REQUIRED i

11.

FHB HVAC (Continued) m c.

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

7 d.

Spent Fuel Pool S

R Q

N.A.

With l

irradiated i

Exhaust Radio-fuel in activity:High spent fuel pool.

M TABLE NOTATION (1)

Each train shall be tested at least every 92 days on a STAGGERED TEST BASIS.

(2) Deleted (3) Deleted (4)

Except relays K807, K814, K829 (Train B only), K831, K845, K852 and K854 (Trains B and C only) which shall be tested at least once per 18 months during refueling and during each COLD SHUTDOWN exceeding 24 cc 11 hours1.273148e-4 days 0.00306 hours 1.818783e-5 weeks 4.1855e-6 months unless they have been tested within the previous 92 days.

r+ <+

[

(5)

Except relay K815 which shall be tested at indicated interval only when reactor coolant pressure is above 700 psig.

gg (6)

Each actuation train shall be tested at least every 92 days on a STAGGERED TEST BASIS. Testing of each actuation train shall include master relay testing of both logic trains.

If an ESFAS instrumentation o-g-

!g channel is inoperable due to failure of the Actuation Logic Test and/or Master Relay Test, increase the surveillance frequency such that each train is tested at least every 62 days c1 a STAGGERED TEST BASIS

<+

unless the failure can be determined by performance of an engineering evaluation to be a single random i

gg failure.

E

During CORE ALTERATIONS or movement of irradiated fuel within containment.

i l

i 4

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

APPLICABILITY:

As shown in Table 3.3-6.

ACTION:

a.

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

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

The provisions of Specification 3.0.3 are not applicable.

c.

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

1 l

l 1

l l

l SOUTH TEXAS - UNITS 1 & 2 3/4 3-50 l

I

O o

REACTOR COOLANT SYSTEM 3/4.4.2 SAFETY VALVES SHUTDOWN LIMITING CONDITION FOR OPERATION 3.4.2.1 A minimum of one pressurizer Code safety valve shall be OPERABLE with a lift setting of 2485 psig 1%.*

APPLICABILITY:

MODES 4 and 5.

ACTION:

With no pressurizer Code safety valve OPERABLE, immediately suspend all operations involving positive reactivity changes and place an OPERABLE RHR loop into operation in the shutdown cooling mode.

SURVEILLANCE RE0VIREMENTS 4.4.2.1 No additional requirements other than those required by Specification 4.0.5.

l i

The lift setting pressure shall correspond to ambient conditions of the valve at nominal operating temperature and pressure.

SOUTH TEXAS - UNITS 1 & 2 3/4 4-7

4' 4

REACTOR COOLANT SYSTEM OPERATING y

)

J LIMITING CONDITION FOR OPERATION 1

3.4.2.2 All pressurizer Code safety valves shall be OPERABLE with a lift j

setting of 2485 psig i 1%.*

APPLICABILITY: MODES 1, 2, and 3.

i ACTION:

(

With one pressurizer Code safety valve inoperable, either restore the inoperable valve to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT l

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 .

i l

SURVEILLANCE REOUIREKENTS 4.4.2.2 No additional requirements other than those required by Specification l

4.0.5.

l l

i i

l

,l 1

2 1

l 1,

l

The lift setting pressure shall correspond to ambient conditions of the valve at nominal operating temperature and pressure.

2 9

4 i

SOUTH TEXAS - UNITS 1 & 2 3/4 4-8 Unit 1 - Amendment No. 59 Unit 2 - Amendment No.-47 4

l 4

)

i

o 3/4.5 EMERGENCY CORE C00llNG SYSTEMS 3/4.5.1 ACCUMULATORS LIMITING CONDITION FOR OPERATION 3.5.1 Each Safety injection System accumulator shall be OPERABLE with:

a.

The isolation valve open and power removed, b.

A contained borated water volume of between 8800 and 9100 gallons, c.

A boron concentration of between 2700 ppm and 3000 ppm.

d.

A nitrogen cover-pressure of between 590 and 670 psig.

APPLICABILITY: MODES 1, 2, and 3*.

ACTION:

a.

With one accumulator inoperable, except as a result of a closed isolation valve or the boron concentration outside the required limits, restore the inoperable accumulator to OPERABLE status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or be in at least H0T STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and l

reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With one accumulator inoperable due to the isolation valve being closed, either open the isolation valve within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or be in at l

least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c.

With the boron concentration of or.e accumulator outside the required limit, restore the boron concentration to within the required limits within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT si'ANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS

4.5.1.1 Each accumulator shall be demonstrated OPERABLE:

a.

At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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, accumulator isolation valve is open.

b.

At least once per 31 days and within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of greater than or equal to 1% of tank volume by verifying the boron concentration of the accumulator solution; and

Pressurizer pressure abova 1000 psig.

SOUTH TEXAS - UNITS 1 & 2 3/4 5-1 Unit 1 - Amendment No. 64,64,59 Unit 2 - Amendment No. 43,43,47 l

. ~.

I 4

EMERGENCY CORE COOLING SYSTEMS i

SURVEILLANCE REOUIREMENTS (Centinued) 3 At least once per 31 days when the.RCS pressure is above 1000 psig c.

by verifying that power to the isolation valve operator is removed.

4 At least once per 18 months by verifying that each accumulator isola-d.

l tion valve opens automatically under each of the following conditions:

1)

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

Uponreceiptofasafetyinjectiontestsignal.

4.5.1.2 Each accumulator water level and pressure channel shall be demon-strated OPERABLE:

At least once per 31 days by the performance of an ANALOG CHANNEL a.

OPERATIONAL TEST, and b.

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

i

)

l d

O o*

O SOUTH TEXAS - UNITS 1 & 2 3/4 5-2

EMERGENCY CORE COOLING SYSTEMS 3/4.5.2 ECCS SUBSYSTEMS - T.x GREATER THAN OR E0 VAL TO 350*F LIMITING CONDITION FOR OPERATION 3.5.2 Three independent Emergency Core Cooling System (ECCS) subsystems shall be OPERABLE with each subsystem comprised of:

a.

One OPERABLE High Head Safety injection pump, b.

One OPERABLE Low Head Safety Injection pump, c.

One OPERABLE RHR heat exchanger, and d.

An OPERABLE flow path capable of taking suction from the refueling water storage tank on a Safety Injection signal and automatically l

transferring suction to the containment sump during the recirculation phase of operation through a High Head Safety injection pump and into the Reactor Coolant System and through a low Head Safety injection pump and its respective RHR heat exchanger into the Reactor Coolant System.

)

APPLICABILITY: H0 DES 1, 2, and 3.*

ACTIOS:

a.

With less than the above subsystems OPERABLE, but with at least two Higt. Head Safety Injection pumps in an OPERABLE status, two Low Head Safety Injection pumps and associated RHR heat exchangers in an OPERABLE status, and sufficient flow paths to accommodate these OPERABLE Safety Injection pumps and RHR heat exchangers,** restore the inoperable subsystem (s) to OPERABLE status within 7 days 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 HOT SHUTDOWN i

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

b.

In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 90 days describing the circumstances of the actuation and the total accumulated actuation cycles to date.

The current value of the usage factor for each affected Safety Injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.

The provisions of Specifications 3.0.4 and 4.0.4 are not applicable for entry into MODE 3 for the Safety injection pumps declared inoperable pursuant to Specification 4.5.3.1.2 provided that the Safety Injection pumps are restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or prior to the temperature of one or more of the RCS cold legs exceeding 375'F, whichever comes first.

- Verify required pumps, heat exchangers and flow paths OPERABLE every I

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

SOUTH TEXAS - UNITS 1 & 2 3/4 5-3 Unit 1 - Amendment No. 4,59 Unit 2 - Amendment No. 47

EMERGENCY CORE COOLING SYSTEMS j

f SURVEILLANCE REQUIREMENTS t

4.5.2 Each ECCS subsystem shall be demonstrated OPERABLE:

At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying that the following valves a.

are in the indicated positions with power to the valve operators removed:

l Valve Number Valve Function Valve Position XS10008 A,B,C High Head Hot Leg Closed Recirculation Isolation XRH0019 A,B,C Low Head Hot Leg Closed Recirculation Isolation b.

At least once per 31 days by:

Verifying that the ECCS piping is full of water by venting the 1)

ECCS pump casings and accessible discharge piping high points, and Verifying that each valve (manual, power-operated, or automatic) 2)

in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

By a visual inspection which verifies that no loose debris (rags, c.

trash, clothing, etc.) is present in the containment which could be transported to the containment sump and cause restriction of the This visual inspection shall pump suctions during LOCA conditions.

be performed:

1)

For all accessible areas of the containment prior to establish-ing CONTAINMENT INTEGRITY, and Of the areas affected within containment at the completion of 2) each containment entry when CONTAINMENT INTEGRITY is established.

At least once per 18 months by a visual inspection of the contain-d.

ment sump and verifying that the subsystem suction inlets are not restricted by debris and that the sump components (trash racks, screens, etc.) show no evidence of structural distress or abnormal corrosion.

I

\\

l SOUTH TEXAS - UNITS 1 & 2 3/4 5-4 I

1

EMERGENCY CORE COOLING SYSTEMS 3/4.5.6 RESIDUAL HEAT REMOVAL (RHR) SYSTEM LIMITING CONDITION FOR OPERATION 3.5.6 Three independent Residual Heat Removal (RHR) loops shall be OPERABLE 4

with each loop comprised of:

a.

10ne OPERABLE RHR pump, b.

One OPERABLE RHR heat exchanger, and c.

One OPERABLE flowpath capable of taking suction from its associated RCS hot leg and discharging to its associated RCS cold leg.*

j APPLICABILITY:

MODES 1, 2 and 3.

j ACTION:

l a.

With one RHR loop inoperable, restore the required loop to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 l

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

b.

With two RHR loops inoperable, restore at least two RHR loops to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within i

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

c.

With three RHR loops inoperable, immediately initiate corrective action to restore at least one RHR loop to OPERABLE status as soon as possible.

SURVEILLANCE REQUIREMENTS l

4.5.6.1 Each RHR loop shall be demonstrated OPERABLE on a STAGGERED TEST BASIS pursuant to the requirements of Specification 4.0.5.

4.5.6.2 At least once per 18 months by verifying automatic interlock action of the RHR system from the Reactor Coolant System to ensure that:

a.

With a simulated or actual Reactor Coolant System pressure signal greater than or equal to 350 psig, the interlocks prevent the valves i

from being opened.

1

Valves M0V-0060 A, B, and C and MOV-0061 A, B, and C may have power removed to support the FHAR (Fire Hazard Analysis Report) assumptions.

4 SOUTH TEXAS - UNITS 1 & 2 3/4 5-11 Unit 1 - Amendment No. 4,44,59 Unit 2 - Amendment No. 48,47

b D

V i

CONTAINMENT SYSTEMS SURVEILLANCE REOUIREMENTS i

~

4.6.1.7.1 Each 48-inch containment purge supply and exhaust isolation valve i

shall be verified to be sealed closed at least once per 31 days.

4.6.1.7.2 At least once per 6 months on a STAGGERED TEST BASIS, the inboard and outboard isolation valves with resilient material seals in each sealed closed 48-inch containment purge supply and exhaust penetration shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than 0.05 L when pressurized to P,.

a 4.6.1.7.3 At least once per 3 months each 18-inch supplementary containment purge supply and exhaust isolation valve with resilient material seals shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than 0.01 L, when pressurized to P,.

4.6.1.7.4 At least once per 31 days each 18-inch supp c untary containment purge supply and exhaust isolation valve shall be verit.ed to be closed or open in accordance with Specification 3.6.1.7.b.

i 3

SOUTH TEXAS - UNITS 1 & 2 3/4 6-13 l

a G

CONTAINMENT SYSTEMS 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS CONTAINMENT SPRAY SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.1 Three independent Containment Spray Systems shall be OPERABLE with each Spray System capable of taking suction from the RWST and transferring suction to the containment sump.

1 APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With one Containment Spray System inoperable, restore the inoperable Spray System to OPERABLE status within 7 days or be in at least HOT STANDBY within j

the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the inoperable Spray System to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVElllANCE REQUIREMENTS 4.6.2.1 Each Containment Spray System shall be dentonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position; b.

By verifying on a STAG (iERED TEST BASIS, that on recirculation flow, l

each pump develops a differential pressure of greater than or equal to 283 psid when tested pursuant to Specification 4.0.5; c.

At least once per 18 months during shutdown, by:

1)

Verifying that each automatic valve in the flow path actuates to its correct position on a Containment Pressure High 3 test signal, and 2)

Verifying that each spray pump starts automatically on a Containment Pressure High 3 test signal coincident with a sequencer start signal, d.

At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

SOUTH TEXAS - UNITS 1 & 2 3/4 6-14 Unit 1 - Amendment No. 59 Unit 2 - Amendment No. 47

9 CONTAINMENT SYSTEMS i

RECIRCULATION FLUID PH CONTROL SYSTEM LIMITING CONDITIONS FOR OPERATION 3.6.2.2 The recirculation fluid pH control system shall be operable with i

between 11,500 lbs. (213 cu. ft.) and 15,100 lbs (252 cu. ft.) of trisodiu.n phosphate (w/12 hydrates) available in the storage baskets in the containment.

1 APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With less than the required amount of trisodium phosphate available, restore the system to the correct amount within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-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 ; restore the system to the correct amount within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVElllANCE REQUIREMENTS 4.6.2.2 During each refueling outage, as a minimum, the recirculation fluid pH control system shall be demonstrated operable by visually verifying that:

a.

C trisodium phosphate storage baskets are in place, and b.

have maintained their integrity, and c.

are filled with trisodium phosphate such that the level is above the indicated fill mark.

4 1

SOUTH TEXAS - UNITS 1 & 2 3/4 6-15 Unit 1 - Amendment No. 37, 42 Unit 2 - Amendment No. Ty, 31 1

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

e-a l

CONTAINMENT SYSTEMS j

(

CONTAINMENT COOLING SYSTEM l

l LIMITING CONDITION FOR OPERATION 3.6.2.3 Three independent groups of Reactor Containment Fan Coolers (RCFC) shall be OPERABLE with a minimum of two units in two groups and one unit in l

the third group.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With one group of the above required Reactor Containment Fan Coolers inoperable, restore the inoperable group of RCFC to OPERABLE status within 7 days 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 .

SURVEILLANCE REQUIREMENTS 4.6.2.3 Each group of Reactor Containment Fan Coolers shall be demonstrated

-OPERABLE:

a.

At least once per 92 days by:

l 1)

Starting each non-operating fan group from the _ control room, and verifying that each fan group operates for at least'15 minutes, and l

2)

Verifying a cooling water flow rate of greater than or equal to i

550 gpm to each cooler.

b.

At least once per 18 months by verifying that each fan group starts automatically on a Safety Injection test' signal, SOUTH TEXAS - UNITS 1 & 2 3/4 6-16 Unit 1 - Amendment No. M,59 Unit 2 - Amendment No. M,47

CONTAINMENT SYSTEMS 3/4.6.3 CONTAINMENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.3 The containment isolation valves shall be OPERABLE with isolation times less than or equal to the required isolation times.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTION:

With one or more of the isolation valve (s) inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and:

Restore the inoperable valve (s) to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , l

a.

or b.

Isolate each affected penetration within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by use of at least l

one deactivated automatic valve secured in the isolation position, or Isolate each affected penetration within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by use of at least l

c.

one closed manual valve or blind flange, or d.

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 .

SURVEILLANCE REQUIREMENTS 4.6.3.1 The isolation valves shall be demonstrated OPERABLE prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by performance of a cycling test, and verification of isolation time.

4.6.3.2 Each isolation valve shall be demonstrated OPERAGLE during the COLD SHUTDOWN or REFUELING MODE at least once per 18 months by:

Verifying that on a Phase "A" Isolation test signal, each Phase "A" a.

isolation valve actuates to its isolation position; b.

Verifying that on a Containment Ventilation Isolation test signal, each purge and exhaust valve actuates to its isolation position; and Verifying that on a Phase "B" Isolation test signal, each Phase "B" c.

isolation valve actuates' to its isolation position.

d.

Verifying that on a Phase "A" Isolation test signal, coincident with j

a low charging header pressure signal, that each seal injection l

valve actuates to its isolation position.

4.6.3.3 The isolation time of each power-operated or automatic valve shall be determined to be within its limit when tested pursuant to Specification 4.0.5.

SOUTH TEXAS - UNITS 1 & 2 3/4 6-17 Unit 1 - Amendment No. 4,30,42,5b 59 l

Unit 2 - Amendment No. 21,31,12, 47 i

.. - - ~.

!c l

CONTAINMENT SYSTEMS 3/4.6.4 COMBUSTIBLE GAS CONTROL l

HYDROGEN ANALYlERS 1

i l

LIMITING CONDITION FOR OPERATION 3.6.4.1 Two independent containment hydrogen analyzers shall be OPERABLE.

l APPLICABILITY: MODES I and 2.

i ACTION:

a.

With one hydrogen analyzer inoperable, restore the inoperable i

analyzer to OPERABLE status within 30 days or be in at least H0T STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , i

b.

With both hydrogen analyzers inoperable, restore at least one analyzer to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-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 .

SURVEILLANCE RE0VIREMENTS 4.6.4.1 Each hydrogen analyzer shall be demonstrated OPERABLE by the performance of a CHANNEL CHECK at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, a channel OPERABILITY verification at least once per 92 days on a STAGGERED TEST BASIS using sample gas containing one volume percent hydrogen, balance nitrogen, and by performing a CHANNEL CALIBRATION at least once per 18 months using sample gas containing ten volume percent hydrogen, balance nitrogen.

50lTTH TEXAS - UNITS 1 & 2 3/4 6-18 Unit 1 - Amendment No. 7#, 42 l

Unit 2 - Amendment No. Jy, 31

o 9

3/4,7 PLANT SYSTEMS 3/4.7.1 TURBINE CYCLE SAFETY VALVES LIMITING CONDITION FOR OPERATION 3.7.1.1 All main steam line Code safety valves associated with each steam generator shall be OPERABLE with lift settings as specified in Table 3.7-2.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a.

With four reactor coolant loops and associated steam generators in operation and with one or more main steam line Code safety valves inoperable, operation in MODES 1, 2, and 3 may proceed provided that within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , either the inoperable valve is restored to OPERABLE l

status or the Power Range Neutron Flux High Trip Setpoint is reduced per Table 3.7-1; otherwise, 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 .

b.

The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE RE0VIREMENTS 4.7.1.1' There are no additional requirements other than those required by Specification 4.0.5 l

l SOUTH TEXAS - UNITS 1 & 2 3/4 7-1 Unit 1 - Amendment No. 4,59 Unit 2 - Amendment No. 47

4 TABLE 3.7-1 MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH SETPOINT WITH INOPERABLE STEAM LINE SAFETY VALVES DURING 4 LOOP OPERATION MAXIMUM NUMBER OF INOPERABLE MAXIMUM ALLOWABLE POWER RANGE SAFETY VALVES ON ANY NEUTRON FLUX HIGH SETPOINT OPERATING STEAM GENERATOR (PERCENT OF RATED THERMAL POWER) 1 87 2

65 3

43 5

SOUTH TEXAS - UNITS 1 & 2 3/4 7-2

. - - - -- --.=- - -.

- -=

O o

PLANT SYSTEMS 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION LIMITING CONDITION FOR OPERATION-3.7.2 The temperatures of both the reactor and secondary coolants in the steam generators shall be greater than 70 F when the pressure of either 1

coolant in the steam generator is greater than 200 psig.

APPLICABILITY:.At all times.

ACTION:

With the requirements of the above specification not satisfied; a.

Reduce the steam generator pressure of the applicable side to less than or equal to 200 psig within 30 minutes, and b.

Perform an engineering evaluation to determine the effect of the overpressurization on the structural integrity of the steam generator.

Determine that the steam generator remains acceptable for continued operation prior to increasing its temperatures above 200 F.

SURVEILLANCE REOUIREMENTS 4.7.2 The pressure in each side of the steam generator shall be determined to be less than 200 psig at least once per hour when the temperature of either the reactor or secondary coolant is less than 70 F.

4 SOUTH TEXAS - UNITS 1 & 2 3/4 7-11

= -._-

i PLANT SYSTEMS 2

3/4.7.3 COMPONENT COOLING WATER SYSTEM 4

4 LIMITING CONDITION FOR OPERATION 3.7.3 At least three independent component cooling water loops shall be OPERABLE.

APPLICABILIII:

MODES 1, 2, 3, and 4.

l

)

ACTION:

L With only two component cooling water loops OPERABLE, restore at least three loops to OPERABLE status within 7 days or be in at least HOT STANDBY within l

4 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 .

l SURVEILLANCE RE0VIREMENTS 4

1 4.7.3 At least three component cooling water loops shall be demonstrated j

OPERABLE:

At least once per 31 days by verifying that each valve outside 4

a.

containment (manual, power-operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured i

in position is in its correct position; and i

b.

At least once per 18 months during shutdown, by verifying that:

1)

Each automatic valve servicing safety-related equipment or j

isolating the non-nuclear safety portion of the system actuates i

to its correct position on a Safety Injection, Loss of Offsite i

Power, Containment Phase "B" Isolation, or Low Surge Tank test j

signal, as applicable, 4

2)

Each Component Cooling Water System pump starts automatically i

on a Safety Injection or Loss of Offsite Power test signal, and I

j 3)

The surge tank level instrumentation which provides automatic j

isolation of portions of the system is demonstrated OPERABLE by

]

performance of a CHANNEL CAllBRATION test.

4 i

c.

By verifying that each valve inside containment (manual, power-j operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured in position is in its correct position prior to entering MODE 4 following each COLD j.

SHUTDOWN of greater than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months if not performed within the previous 31 days.

i t

}

i SOUTH TEXAS - UNITS 1 & 2 3/4 7-12 Unit 1 - Amendment No. 4,59 l

Unit 2 - Amendment No. 47 4

4 m._

n.. m..,

,,.m..,,,

,-.m.,m...

o s

PLANT SYSTEMS i

3/4.7.6 (This specification number is not used.)

l l

l I

I f

SOUTfi TEXA5 - UNITS 1 & 2 3/4 7-15 f-

1 PLANT SYSTEMS 3/4.7,7 CONTROL ROOM MAKEUP AND CLEANUP FILTRATION SYSTEM LIMITING CONDITION FOR OPERATION 3.7.7 Three independent Control Room Makeup and Cleanup Filtration Systems shall be OPERABLE.

]

APPLICABILITY:

All MODES.

ACTION:

MODES 1, 2, 3 and 4:

With one Control Room Makeup and Cleanup Filtration System a.

inoperable, restore the inoperable system to OPERABLE status within 7 days 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 .

b.

With two Control Room Makeup and Cleanup Filtration Systems inoperable, restore at least two systems to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least H0T STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and l

i in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , j

MODES 5 and 6:

a.

With one Control Room Makeup and Cleanup Filtration System l

inoperable, restore the inoperable system to OPERABLE status within 4

7 days or initiate and maintain operation of the remaining OPERABLE Control Room Makeup and Cleanup Filtration Systems in the recirculation and makeup air filtration mode.

b.

With two Control Room Makeup and Cleanup Filtration Systems inoperable, or with the OPERABLE Control Room Makeup and Cleanup Filtration System, required to be in the recirculation and makeup air filtration mode by ACTION a., not capable of being powered by an OPERABLE emergency power source, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.

j SURVEILLANCE REQUIREMENTS 4.7.7 Each Control Room Makeup and Cleanup Filtration System shall be demonstrated OPERABLE:

At least once per 12 houYs by verifying that the control room air i

a.

temperature is less than or equal to 78'F; b.

At least once per 92 days on a STAGGERED TEST BASIS by initiating, l

from the control room, flow through the HEPA filters and charcoal adsorbers of the makeup and cleanup air filter units and verifying that the system operates for at least 10 continuous hours with the makeup filter unit heaters operating; SOUTH TEXAS - UNITS 1 & 2 3/4 7-16 Unit 1 - Amendment No. 59 Unit 2 - Amendment No. 47 4

z

s PLANT SYSTEMS 3/4.7.13 AREA TEMPERATURE MONITORING LIMITING CONDITION FOR OPERATION 3.7.13 The temperature of each area shown in Table 3.7-3 shall not be exceeded for more than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or by more than 30*F.

J APPLICABILITY:

Whenever the equipment in an affected area is required to be OPERABLE.

ACTION:

With the temperature inside any QDPS auxiliary processing cabinet a.

exceeding 110*F for more than 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , prepare an engineering evaluation within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to determine the temperature effects on QDPS OPERABILITY and service life.

The provisions of Specification 3.0.3 are not applicable.

b.

With one or more areas exceeding the temperature limit (s) shown in Table 3.7-3 for more than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , prepare and submit to the Commission within 30 days, pursuant to Specification 6.9.2, a Special Report that provides a record of the cumulative time and the amount by which the temperature in the affected area (s) exceeded the limit (s) and an analysis to demonstrate the continued OPERABILITY of the affected equipment.

The provisions of Specification 3.0.3 are not applicable.

With one or more areas exceeding the temperature limit (s) shown in c.

Table 3.7-3 by more than 30*F, prepare and submit a Special Report as required by ACTION b. above and within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either restore the area (s) to within the temperature limit (s) or declare the equipment in the affected area (s) inoperable.

SURVEILLANCE RE0VIREMENTS 4.7.13 The temperature in each of the areas shown in Table 3.7-3 shall be determined to be within its limit at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

l N

4 SOUTH TEXAS - UNITS 1 & 2 3/4 7-31 Unit 1 - Amendment No. 4,59 Unit 2 - Amendment No. 47

~

-. =-

i e

4 TABLE 3.7-3 AREA TEMPERATURE MONITORING AREA TEMPERATURE LIMIT (*F) 1.

Relay Room

< 78 (Electrical Auxiliary Building E1. 35'0")

2.

Switchgear Rooms

< 85 (Electrical Auxiliary Building E1. 10'0",

35'0",60'0")

3.

Electrical Penetration Spaces

< 103 (Electrical Auxiliary Building E1. 10'0",

35'0",60'0")

4.

Safety Injection and Containment Spray 1 101 Pump Cubicles (Fuel Handling Building El. -29'0")

5.

Component Cooling Water Pump Cubicles

-< 112 (Mechanical Auxiliary Building E1. 10'0")

6.

Centrifugal Charging Pump Cubicles

< 132 (Mechanical Auxiliary Building E1. 10'0")

7.

Hydrogen Analyzer Room

< 102

~

(Mechanical Auxiliary Building El. 60'0")

8.

Boric Acid Transfer Pump Cubicles

< 101 (Mechanical Auxiliary Building El. 10'0")

l (Diesel Generator Building El. 25'0")

-< 101*

9.

Standby Diesel Generator Rooms 10.

Essential Cooling Water Pump Rooms

< 101

~

(Essential Cooling Water Intake l

Structure E1, 34'0")

11.

Isolation Valve Cubicles

< 101

~

(Isolation Valve Cubicle E1. 10' 0")

12.

Qualified Display Processing System Rooms 1 94**

(Electrical Auxiliary Building El. 10'0")

Temperature limit is 5 120*F when testing the standby diesel generator pursuant to Surveillance Requirement 4.8.1.1.2.e.7).

- Measurement inside QDPS auxiliary processing cabinets.

SOUTH TEXAS - UNITS 1 & 2 3/4 7-32

.

ML20067D175

Text

Attachment:

Attachment:

Navigation menu

Search