Text

Proposed Changes to Tech Specs 3.3.2,Table 3.3-5,Page 3/4 3-29 Re Auxiliary Feedwater Pump Load Sequence Delay
	ML20052H669
Person / Time
Site:	San Onofre
Issue date:	05/19/1982
From:	; SOUTHERN CALIFORNIA EDISON CO.
To:	;
Shared Package
ML13310A414	List: ML13310A413; ML20052H669;
References
	NUDOCS 8205210323
	Download: ML20052H669 (23)
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REACTIVITY CONTROL SYST[M5 BORATED WATER SOURCE - SHUTDOWN LIMITING CONDITION FOR OPERATION 2.1.2.7 As a minimum, one of the following borated water sources shall be OPERABLE:

a.

One boric acid makeup tank and at least one associated heat tracing circuit with the tank contents in accordance with figure 3.1-1.

b.

The refueling water storage tanks with:

1.

A minimum borated water volume of 5465 gallons above the ECCS suction connection, 2.

A minimum baron concentration of 1720 ppm, and 3.

A solution temperature between 40 F and 120 f.

APPLICABILITY:

MODES 5 and 6.

ACTION:

With no borated water sources OPERABLE, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.

^

SURVEILLANCE REQUIREMENTS 4.1.2.7 The above required borated water source shall be demonstrated OPERABLE:

a.

At least once per 7 days by:

1.

Verifying the boron concentration of the water, 2.

Verifying the contained borated water volume of the tank, and-3.

Verifying the boric acid makeup tank solution temperature when it is the source of borated water.

b.

At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying the RWSI temperature when it is the source of borated water when the outside air temperature is less than 40*F.

hof03 SAN ON0fRE-UNIT 2 3/4 1-12

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'l REACTIVITY CONTROL SYSTEMS BORATED WATER SOURCES - OPERAllNG

~

LIMITING CONDITION FOR OPikATION 3.1.2.8 Each of the following borated water sources shall be OPERABLE:

a.

At least one Doric acid n.akeup tan 6 and at least one associated heat tracing circuit with the contents of the tanks in accordance with figure 3.1-1, and b.

The refueling water storage tank with:

1.

A minimum contained borated water volume of 362,800 gallons above the ECCS suction connection, 2.

Between 1720 and 2300 ppm of boron, and 3.

A solution temperature between 40 f and 120*f.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

a.

With the above required boric acid makeup tank inoperable, restore the tank to OPERABLE statu:. 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 and borated to a SHUTDOWN MARGIN equivalent to at least 2% delta k/k at 200 F; restore the above required boric acid makeup tank to OPERABLE status within the next 7 days or be in COLD SHUIDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

b.

With the refueling water tank inoperable, restore the tank to OPERABLE status within one hour or be in at least H01 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 4.1.2.8 Each borated water sources shall be demonstrated OPERABLE:

a.

At least once per 7 days by:

1.

Verifying the baron concentration in the water, 2.

Verifying the contained borated water volume of the water i

source, and 3.

Verifying the boric acid makeup tank solution temperature.

t b.

At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying the RWST temperature when the outside air temperature is less than 40 F.

SAN ONOFRE-UNIT 2 3/4 1-14.

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i REACTIVITY CONTROL SYSTEMS PART LENG1H CEA INSERTION LIMITS LIMITING CONDI TION FOR OPERATION 3.l.3.7 The position of the part length CEA group shall be restricted to prevent the neutron absorber section of the part length CEA group from covering the same axial segment of the fuel assemblies for a period in excess of 7 EFPD out of any 30 EFPG period.

APPLICABILITY:

MODES 1 and 2.

ACTION:

With the neutron absorber section of the part length CEA group covering any same aXIdl segment of the fuel dssemblies for a period exceeding 7 EFPD out of any 30 EfPD period, either:

a.

Reposition the part length CEA group to ensure no neutron absorber section of the part length CEA group is covering the same axial segnient of the fuel assemblies within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , or b.

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 REQUIHEMENTS 4.1.3.7 The position of the part length CEA group shall be determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

SAN ONOFRE-UNIT 2 3/4 1-25

TABLE 3.3-1 (Continued)

TABLE N01A110N To be OPERABLE prior to first exceeding 5% RATED THERMAL POWER.

With the piotective system trip breakets in the closed position, the CEA drive system capable of CEA withdrawal, and fuel in the reactor vessel.

1he provisions of Specification 3.0.4 ar e not applicable.

~

(a) Trip may be manually bypassed above 20 1 of RATfD THERMAL POWLR; bypass shall,g%ofRATEDTHERMALPOWER.e automatically removed when THERMAL POWER to 10 (b) Trip may be manually bypassed below 400 psia; bypass shall be automatically removed whenever pressurizer pressure is greater than or equal to 400 psia.

(c) Trip may be manually bypassed below 10'4% of RATED THERMAL POWER; bypass shall be autg% of RATED THERMAL POWER.matically removed when lHERMAL POWER i During testing pursuant to equal to 10 Special Test Exception 3.10.3, trip may be manually bypassed below 5% of RATED 1HERMAL POWER; bypass shall be automatically removed when THERMAL POWER is greater than or equal to 1% of RATED THERMAL POWER.

(d) Trip may be bypassed during testing pursuant to Special Test Exception 3.10.3.

(e) See Special Test Exception 3.10.2.

(f) Each channel shall be comprised of two trip breakers; actual trip logic shall be one out of-two taken twice.

(g) Trip may be bypassed below 55% RATED THERMAL POWER.

ACTION STATEMENTS With the number of channels OPERABLE one less than required by ACTION 1 the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the protective system trip breakers.

With the number of channels OPERABLE one less than the Total ACTION 2 Number of Channels, STARTUP and/or POWER OPERATION may continue provided the inoperable channel is placed in the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

If the inoperable channel is l

bypassed, the desirability of main'.aining this channel in the bypassed condition shall be reviewed in accordance with l

Specification 6.5.1.6k.

The channel shall be returned to OPERABLE status no later than during the next COLD SHUTDOWN.

SAN ONOFRE-UNIT 2 3/4 3-4

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E TABLE 3.3-3 S

a ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM j.

3 TOTAL NO.

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

1.

SAFETY INJECTION (SIAS) a.

Manual (Trip Buttons) 2 sets of 2 1 set of 2 2 sest of 2 1,2,3,4 8

b.

Containment Pressure -

High 4

2 3-1, 2, 3 9*,

10*

c.

Pressurizer Pressure -

tow 4

2 3

1, 2, 3(a) 9*,

10, d.

Automatic Actuation -

Logic 4

2 3

1, 2, 3, 4 9*, 10, 2.

CONTAINMENT SPRAY (CSAS) a.

Manual (Trip Buttons) 2 sets of 2 1 set of 2 2 sets of 2 1, 2, 3, 4 8

b.

Containment Pressure --

{

High - High 4

2(b) 3 1,2,3 9*,

10*

w c.

Automatic Actuation Logic 4

2 3

1, 2, 3, 4 9*,

10*

^

3.

CONTAINMENT ISOLATION (CIAS) a.

Manual CIAS (Trip Buttons) 2 sets of 2 I set of 2 2 sets of 2 1, 2, 3, 4 8

b.

Manual SIAS (Trip Buttons) (c) 2 sets of 2 1 set of 2 2 sets of 2 1, 2, 3, 4 8

c.

Containment Pressure -

High 4

2 3

1, 2, 3 9, 10 d.

Au ic Actuation 4

2 3

1,2,3,4 9*,

10*

e l*

(

1

I TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION E

MINIMUM m

A TOTAL NO.

CHANNELS CHANNELS APPLICABLE g

FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERASLE MDDES ACTION 4.

MAIN STEAM LINE ISOLATION a.

Manual (Trip 2/ steam 1/stean 2/ operating 1,2,3 11 Buttons) generator generator steam generator b.

Steam Generator 4/ steam 2/ steam 3/ steam 1, 2, 3 9*,

10*

Pressure - Low generator generator generator c.

Automatic Actuation 4/ steam 2/ steam 3/ steam 1, 2, 3 9*,

10*

Logic generator generator generator 5.

RECIRCULATION (RAS) g,

^

a.

Refueling Water Storage Y

Tank - Low 4

2 3

1,2,3 9*,

10*

b.

Automatic Actuation Logic 4

2 3

1,2,3 9*,

10*

6.

CONTAINMENT COOLING (CCAS) a.

Manual CCAS (Trip Buttons) 2 sets of 2 1 set of 2 2 sets of 2 1, 2, 3, 4 8

b.

Manual SIAS (Trip Buttons) 2 sets of 2 I set of 2 2 sets of 2 1,2,3 8

c.

Automatic Actuation Logic 4

2 3

1, 2, 3, 4 9*,

10*

o v..

TABLE 3.3-3 (Continued)

TABLE NOTATION

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(a) Trip f unction may be bypassed in this MODE when pressurizer pressure is less than 400 psia; bypass shall be outumatically removed when pressurizer pressure is greater than or equal to 500 psia.

(b) An SIA5 signal is first necessary to enable CLAS logic.

(c) Actuated equipment only; does not result in CIAS.

The provisions ut Specification 3.0.3 are not applicable.

The provisions of Specification 3.0.4 are not applicable.

With irradiated fuel in the storage pool.

ACTION STATEME*{S ACTION 8 With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

ACTION 9 -

With the number of channels OPERABLE one less than the Total Number of Channels, STAR 10P and/or POWER OPERATION may continue provided the inoperable channel is placed in the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

If the inoperable channel is bypassed, the desirability of maintaining this channel in the bypassed condition shall be reviewed in accordance with Specification 6.5.1.6k.

The channel shall be returned to OPERAbt[ status no later than during the next COLD SHUTDOWN.

With a' channel process measurement circuit that affects multiple functional units inoperable or in test, bypass or trip all associated functional units as listeJ below.

Process Measurement Circuit functional Unit Bypassed 1.

Containment Pressure - High Containment Pressure - High (ESF)

Containment Pressure - High (RPS) 2.

Steam Generator Pressure -

Steam Generator Pressure - Low Low Steam Generator AP 1 and 2 (EFAS) 3.

Steam Generator Level Steam Generator Level - Low Steam Generator Level - High l

Steam Generator aP (EFAS)

SAN ONOFRE-UNil 2 3/4 3-19

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E TABLE 3.3-4 9

Q ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES U

5; g_

ALLOWABLE z

FUNCTIONAL UNIT TRIP VALUE VALUES w-N 1.

SAFETY INJECTION (SIAS) a.

Manual (Trip Buttons)

Not Applicable Not Applicable b.

Containment Pressure - High 5 2.95 psig

$ 3.14 psig c.

Pressurizer Pressure - Low 2 1806 psia (1) 3 17f-3 psia (1) d.

Automatic Actuation Logic Not Applicable Not Aoplicable 2.

CONTAINMENT SPRAY (CSAS) a.

Manual (Trip Buttons)

Not Applicable Not Applicable b.

Containment Pressure -- High-High

$ 16.14 psig 5 16.83 psig c.

Automatic Actuation Logic Not Applicable Not Applicable 3.

CONTAINMENT ISOLATION (CIAS) w a.

Manual CIAS (Trip Buttons)

Not Applicable Not Applicable b.

Manual SI AS (Trip Buttons)(5)

Not Applicable Net Applicable M

c.

Containment Pressure - High

$ 2.95 psig 3 3.14 psig d.

Automatic Actuation Logic Not Applicable Not Applicable 4.

MAIN STEAM ISOLATION (MSIS) a.

Manual (Trip Buttons)

Not Applicable Not Applicable b.

Steam Generator Pressure - Low 3 729 psia (2) 3 711 psia (2) c.

Automatic Actuation Logic Not Applicable Not Applicable

,e 5.

RECIRCULATION (RAS)

I' a.

Manual RAS (Trip Buttons)

Not Applicable Not Applicable

.{.

b.

Refueling Water Storage Tank 18.5% of tap span 19.27% 1 tap span 1 17.73%

c.

Automatic Actuation Logic Not Applicable Not Applicable

/*

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i

r lable 3.3-5 (Continued)

INITI ATING SIGNAL AND f UNCTION RESPONSE TIME (SEC)

\\t -

5.

Steam Generator Pressure - Low 0'

e.

M515 (1) Main Steam Isolation (MSIV) 20.9 (2) Main f eedwater Isolation 10.9 6.

Retim l ing W.st et rtorage Tonb - l ow e

a.

RAS (1) Containment Sump Valves Open 50.7" (2) ECC5 Miniflow Valves Shut 40.7" 7.

4.16 kv Emergency Bus undervoltage a.

LOV (loss of voltage and degraded voltage) figure 3.3-1 8.

Steam Generator Level - Low (and No Pressure-tow Trip?

a.

EFAS (1) Auxiliary feedwater (AC trains) 40.9*

(2) Auxiliary feedwater (steam /DC train) 30.9 s

9.

Steam Generator Level - Low (and AP - High) a.

EFAS (1) Auxiliary feedwater (AC trains) 40.9*

(2) Auxiliary feedwater (Steam /DC train) 30.9-10.

Control Room Ventilation Airborne Radiation a.

CRIS (1) Control Room Ventilation - Emergency Mode Not Applicable 11.

Control Room Toxic Gas (Chlorine) a.

TGIS (1) Control Room Ventilation - Isolation Mode 16 (NOTE 5) j 12.

Control Room Toxic Gas ( Ammonia) a.

1G15

('" *

(1) Control Room Ventilation - Isolation Mode 36 (NOTE 5)

SAN ON0fRE-UNIT 2 3/4 3-29

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.s lable 3.3-5 (Continued)

INITI ATING SIGNAL AND f LINCTION RESPONSE TIME (SEC) 13.

Control Room Tomic Gas (Butane / Propane) a.

TGIS (1) Control Room Ventilation -

Isolation Mode 36 (NOTE 5) 14.

Cunt rol kooni 1on ic bas (Carbon Dio> ide) a.

TGIS (1) Control Room Ventilation -

Isolation Mude 36 (NOTE 5) 15.

Fuel Handling Building Airborne Radiation a.

FHIS (1) Fuel Handling building Post-Accident Cleanup Filter System Not Applicable 16.

Containment Airborne Radiation a.

CPIS (1) Containment Purge Isolation 2 (NOTE 2) 17.

Containment Area Radiation a.

CPIS (1) Containment Purge Isolation 2 (NOTE 2)

NOTE S:

1.

Response times include movement of valves and attainment of pump or blower discharge pressure as applicable.

Emergency diesel generator starting delay (10 sec.) and sequence loading delays for SIAS are included.

2.

Response time includes emergency diesel generator starting delay (applicable to AC s.otor operated valves other than containment purge valves), instrumentation and logic response only.

Refer to table 3.6-1 for containment isolation valve closure times.

3.

All CIAS-Actuated volves except M51Vs and MFIVs.

4.

CCW non-critical loop isolation valves 2HV-6212, 2HV-6213, 2HV-6218 and 2HV-6219.

5.

Response time includes instrumentation, logic, and isolation damper closure times only.

SAN ONOFRC-UNIT 2 3/4 3-30 L

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TABLE 3.3-10 v,

E I

ACCIDENT MONITORING INSTRUMENTATION (CONTINUED) g A

REQUIRED MINIMLM cb NUMBER Of CHANNELS

{

INSTRUMENT CHANNEL 5 OPERABLE 19.

Containment Area Radiation - High Range 2

1 20.

Main Steam Line Area Radiation 1/ steam line N.A.

21.

Condenser Evacuation System Radiation Monitor -

1 N.A.

Wide Range 22.

Purge / Vent Stack Radiation Monitor - Wide Range

2 1

s-23.

Cold Leg HPSI flow 2/ cold leg 1/ cold leg 24.

Hot Leg HPSI flow 1/ hot leg N.A.

Y 4

NOTES:

The two required channels are the Unit 2 monitor and the Unit 3 monitor.

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.,.e REACTOR COOLANT SYSIIM HOT SHUTOOWN

\\s.

LIMITING CONDITION FCR OPERATION 3.4.1.3 a.

At least two of the loop (s)/ train (s) listed below shall be OPERABLE:

1.

Reactor Coolant Loop 1 and its associated steam generator and at least one associated Reactor Coolant pump,**

2.

Reactor Coolant Loop 2 and its associated steam generator and at least one associated Reactor Coolant pump,"*

3.

Shutdown Cooling Train A, 4.

Shutdown Cooling Train B.

b.

At least one of the above Reactor Coolant loops and/or shutdown cooling trains shall be in operation."

APPLICABILITY:

MODE 4#

ACTION:

a.

With less than the above required Reactor Coolant loops and/or shutoown cooling trains OPERABLE, immediately initiate correc-tive action to return the required loops / trains to OPERABLE status as soon as possible; if the remaining OPERABLE loop is a shutdown cooling train, be in COLD SHUTDOWN within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b.

With no Reactor Coolant loop or shutdown cooling train in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immedi-ately initiate corrective action to return the required coolant loop / train to operation.

~

0With the Reactor Coolant System cold leg temperature less than or equal to 235*F, the 50CS isolation valves HV-9337, HV-9339, HV-9377, and HV-9378 shall be open with the SDCS reliet valve PSV-9349 OPERABLE.

A All Reactor Coolant pumps and shutdown cooling pumps may be de-energized for up to I hour provided (1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration, and (2) core outlet temperature is maintained at least 10*F below saturation temperature.

22 A Reactor Coolant pump shall not be started with one or more of the Reactor Cooisnt Syctes cold leg temperatures less than or equal to 235*F unless

1) the pressurizer water volume is less than 900 cubic feet or 2) the secondary water temperature of each steam generator is less than 100*F above each of

~

the Reactor Coolant System cold leg temperatures.

SAN ONOFRE-UNIT 2 3/4 4-3

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HE ACIOR COOLANT SYSlEM COLD SHUTDOWN - LOOPS FItt fD

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LIMITING CONDITION FOR OPfRATION 3.4.1.4.1 At least one shutdown cooling train shall be OPERABLE with all suction line volves open drid in oper ation," and either:

One odditional shutdown cooling train shall be OPERABLE,# or a.

b.

lhe secondary side water level of each steam generator shall be greater tnan 101 (wide range).

APPi lCAbil l 1 Y:

MODE b, with Reactor Coolant loopy *illed.

AC110N:

a.

With less than the above required shutdown trains / loops OPERABLE or with less than the required steam generator level, immediately initiate currective action to return the required trains / loops to OPLkABLE stotus or resture the required level as soon as possible.

b.

With no shutdown cooling train in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required shutdown cooling train to operation.

SURVEILLANCE REQUIREMENTS 4.4.1.4.1.1 The secondary side water level of at least two steam generators, when required, shall be determined to be within limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.4.1.2 The shutdown cooling train shall be determined to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

WOne shutaown cooling train may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided the other shutdown cooling train is OPERABLE and in operation.

m The shutdown cooling pump may be de energized for up to I hour provided

1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration, and 2) core outlet temperature is maintained at least 10*F below saturation temperature.

n O

e SAN ONOFRl-UNil 2 3/4 4-5 l

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REACTOR COOLANT SYSTEM 3 /4. 4. 3 PRE 550R17ER LIMITING CONDil10N FOR OPERATION 3.4.3 The pressurizer shall be OPERABLE with a water volume of less than or equal to 900 cubic feet and at least two groups of pressurizer heaters each having a capacity of at least 150 kw.

APPLICABILITY:

MODES 1, 2 and 3.

ACTION:

a.

With one group of pressurizer heaters inoperable, restore at least two groups 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 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 the pressurizer otherwise inoperable, be in at least HOT STANDBf with the reactor trip breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTD0dh witnin the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.4.3.1 The pressurizer water volume shall be determined to be within its liait at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.3.2 The pressurizer heaters shall be demonstrated OPERABLE at least once p;r 18 months by manually energizing the heaters.

(

4.4.3.3 The capacity of each of the above required groups of pressurizer heators shall be verified by energizing the heaters and measuring circuit current at least once per 92 days.

i l

k SAN ON0fRE -UNIT S

%KLO-[3

../ a-.%...'..x RE ACluk COOL Ah! LYSif M OVfRPRESSUR[ PR01ECT10N SYS1iMS RCS TEMPERATURE I 235*f LIMITING CONDITION FOR OPERATION 3.4.8.3 1 At least one of the fullowing overpressure protection systems shall be OPERABLE:

a.

The Shutdown Cooling System (SDCS) Relief Valve (PSV9349) with a lift setting of less than or equal to 402 psig, or, b.

The Reactor Coolant System depressurized with an RCS vent of greater than or equal to S.6 square inches.

APPLICABILITY:

MODE 4 when the temperature of one any RCS cold leg is less than or equal to 235*f; Hode S; Moce 6 with the reactor vessel head on.

ACTION:

a.

With the SDCS Relief Valve inoperable, reduce T t

less than avg 200 f, depressurize and vent the RCS through a greater than or equal to S.6 square inch vent within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

b.

With one or both SDCS Relief Valve isolation valves in a single SDCS Relief Valve isolation valve pair (valve pair 2HV9337 and 2HV9339 or valve pair 2HV9377 and 2HV9378) closed, open the closed valve (s) within 7 days or reduce T to less than 200*f, depres-surizeandventtheRCSthroughaOE0aterthanorequaltoS.6 inch vent within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

c.

In the event either the SDCS Relief Valve or an RCS vent is used to mitigate a RCS pressure transient, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 30 days.

The report shall describe the circumstances initi-ating the transient, the effect of the SDCS Relief Valve or RCS vent on the transient and any corrective action necessary to prevent recurrence.

d.

The provisions of Specification 3.0.4 are not applicable.

SURVE]LLANCE REQUIREMENTS 4.4.8.3.1.1 The SDCS Relief Valve shall be denonstrated OPERABLE by:

a.

Verifying at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months when the SDCS Relief Valve is l

being used for overpressure protection that at least one pair of SDCS Relief Valve isolation valves (valve pair 2HVS337 and 2HV9339 or valve pair 2HV9377 and 2HV9378) is open.

SAN ON0fRE-UNIT 2 3/4 4-32

PLANT SYSTfM5 HAIN STEAM LINE ISOLATION VALVf5 k.,.

LIMITING CONDITION FOR OPERATION s

3. 7.1. 5 Each main steam line isolation valve shall be OPERABLE.

APPLICABILITY:

MODES 1, 2 and 3.

ACT]ON:

With one main steam line isolation valve inoperable but open, MODE 1 POWER OPERATION may continue provided the inoperable valvi is restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; otherwise, rt?>ce power to less than or equal to 5 percent RATED THERMAL POWER within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

With one n,ain steam line isolation valve inoperable, MODES 2 and 3 subseqent operation in MODES 2 or 3 may proceed provided:

a.

The isolation valve is maintained Closed.

b.

The provisions of Specification 3.0.4 are not applicable.

Otherwise, be in at least HOT STANDBY with the next 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' SURVEILLANCE REQUIREMENTS

4. 7.1. 5 Each main steam line isolation valve shall be demonstrated OPERABLE by verifying full closure within 5.0 seconds when tested pursuant to Specification 4.0.5.

t g

e SAN ONOFRE-UNIT 2 3/4 7-9

4-

....,.:A s

TABLE 3.10-1 RADI ATION MONIl0 RING / SAMPLING EXCEPTIONS s_

l.

Testing performed pursuant to FSAR 5ection 11.5.2.1.5.2 in startup program shall satisfy the initial CHANNEL CALIBRA110N for the following monitors prior to first exceeding 5% RATED THERHAL POWER:

a.

Control Roosi Airborne Monitors 2RT-7824 2RT-7825 b.

Containment Airborne Monitors 2RT-7804-1 2RT-7807-2 c.

Containment Purge Area Monitors 2RT-7856-1 2RT-7857-2 d.

Containment Area Radiation -

2RT-7820-1 High Range Monitors 2RT-7820-2 e.

Plant Vent Stack Airborne Monitor 2/3RT-7808 f.

Radwaste Discharge Line Monitor 2/3RT-7813 g.

Blowdown Neutralization Sump Monitor 2RT-7817 h.

Turbine Building Sump Monitor 2RT-7821 2.

The following monitors and samplers shall be OPERABLE prior to first exceeding 5% RATED THERMAL POWLR:

a.

Main Steam Line Area Monitors 2RT-7874A1 2RT-784781 2RT-7875A1 2RT-7875B1 b.

Condenser Evacuation System -

2RT-7870-1 Wide Range Monitor c.

Purge / Vent Stack Monitors -

2RT-7865-1 Wide Range 3RT-7865-1 d.

Plant Vent Stack Flow Rate Monitor e.

Containment Purge Flow Rate Monitor f.

Condenser Evacuation System lodine Sampler Particulate Sampler Flow Rate Monitor 3.

The Steam Jet Air Ejector Monitor (2RT-7818) shall be OPERABLE prior to initial criticality.

.,/

SAN ON0fRE-UNIT 2 3/4 10-6

. l...

c..

..n SPECIAL lE51 EXCfP110NS MINIMUM T[MPIRATUl:[ FOR CHillCAtilf 11MITING CONDITION F OR OPfRATION 3.10.6 The n,inimum temper ature f or criticality limits to Specification 3.1.1.4 and the MODE 2 cetinition of lable 1.1 may be suspended during low temperature PHYSICS ILSlS to a minimum temperature of 320'f provided:

a.

The THERMAL POWER does not exceed Si of RATED THERMAL POWER.

b.

The reactor trip setpoints on the OPERABLE Linear Power Level - High neutron flux monitoring channels are set at i 20% of RAlED THERMAL POWER, and c.

The Reactor Coolant System temperature and pressure relationship and the minir..um temperaure for criticaliaty is maintained within the acceptable region of operation shown on Figure 3.4-2.

APPLICABILITY:

MODE 2."

ACTION:

a.

With the THERMAL POWER > 5 percent of RATED THERHAL POWER, immediately trip the reactor, b.

With the Reactor Coolant System temperature and pressure relationship and/or the minimum temperature for criticality within the region of unacceptable operatinn on figure 3.4-2, immediately trip the reactor and, if necessary, restore the temperature pressure relationship to within its limit within 30 minutes; perform the engineering evaluation required by Specification 3.4.8.1 prior to the next reactor criticality.

SURVEILLANCE REQUIREMENTS 4.10.6.1 The Reactor Coolant System temperature and pressure relationship cnd the minimum temperature for criticality shall be verified to be within the ecceptable region for operation of Figure 3.4-2 at least once per hour.

4.10.6.2 The THERHAL POWER shall be determined to be < 5% of RATED THERHAL

~

POWER at least once per hour.

4.10.6.3 The Reactor Coolant System temperature shall be verified to be graater than or equal to 320*F at least once per hour.

4.10.6.4 Each Logarithmic Power Level and Linear Power Level channel shall be subjected to a CHANNEL fUNC110NAL lEST within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months prior to initiating low temperature PHYSICS TESTS.

Ifirst core only, prior to first exceeding 5% RATED THERMAL POWER.

SAN ONOFRE-UNIT 2 3/4 10-8 D

7

..s PLANT SYSTEMS BASES FIRE SUPPRESSION SYSTEMS (Continued)

In the event the fire suppression water system becomes ir. operable, immediate corrective measures must be taken since this system provides the cajor fire suppression capability of the plant.

ine requirement for a twenty -

four hour report to the Commission provides for prompt evaluation of the ccceptability of the corrective measures to provide adequate fire suppression capability for the continued protection of the nucle-plant.

)

3/4.7.9 FIRE RATED ASSEMBLIES The OPERABILITY of the fire barriers and barrier penetrations ensure that fire damage will be limited.

These design features minimize the possibility of a single fire involving more than one fire area prior to cetection and extinguishment.

The fire barriers, fire barrier penetrations for conduits, cable trays and piping, fire windows, fire dampers, and fire doors are periodically inspectea to verify their OPERABILITY.

t 9=

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9 e

..i

.e ELECTRIC POWER SYSTEMS BASES

..s A.C. SOURCES, D.C. SOURCES AND ONSITE POWER DISTRIBUTION SYSTEMS (Continued) as well as' operation-of loss of voltage logic, is the same as for the primary connection using the reserve auxiliary transf ormer, with the exception of no transfer to the companion unit.

The Surveillance Regyirements for demonstrating the OPERABILITY of the diesel generators are in accordance with the recomniendations of Regulatory Guides 1.9 " Selection of Die:,el Generator Set Capacity for Standby Power Supplies," March 10, 1971, and 1.i0s "Periudic Testing of Diesel Generator Unit:, Used as Onsite Electric Fower Syn.tems at Nuclear Power Plants," Revision 1 August 1977, and 1.137, "fu.l Oil Systems for Standby Diesel Generators,"

Revision 1,-October 19f9 Additionally, Regulatory Guide 1.9 allows loading of the diesel generator to its 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months ' rating in an accident situation.

The full load, continuous operation rating for each diesel generator is 4700 kw, while the calculated eccident loading is 4000 kw.

No 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months loading has been specified by the diesel generator manuf acturer ana, as a result the f ull loading rating of 4700 kw is conservatively established as tha 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating.

Diesel fre-quency droop restrictions are established due to HPSI flow rate considerations.

The Surveillance Requirement for demonstrating the OPERABILITY of the Station batteries are based on the recommenactions of Regulatory Guide 1.129,

" Maintenance lesting and Replacement of Large 4esd Storage Batteries for Nuclear Power Plants," February 1978, and IEEE Std 450-1980, "lEEE Recommer;ded Practice for Maintenance,-Testing, and Replace, rent of Large Lead Storage Batteries for Generating Stations and Substaticm."

Verifying average electrolyte temperatbre above the minimum for which the battery was sized, total bettery terminal volt,q;e onfloat charge, connection resistance values and the performance of battery service and discharge tests esures the effectiveness of the charging system, tha ability to handle high discharge rates and compares the battery capr. city at' that time with the uted s

Capacity.

N w

l Table 4.3-2 specifies the normal lir its for each designated pilot cell and each connected cell for electrolye level, float voltage and specific gravity.

The limits for the designated pilot cells float voltage and specific i

gravity, greater than 2.13 volts and.015 below the manufacturer's full charge specific gravity or a battery charger current that had stabilized at a low value, is characteristic of a charged cell with adequate capacity.

The normal l

limits for each connected cell for float voltage and specific gravity, greater than 2.1.3 volts and not more than.020 below the manufacturer's full charge specific gravity with an' average specific gravity of all.the cdnnected cells

.not more trian.01_0 below the manuf acturer's full charge specific gravity, Ciisures the'0PERASILITY and capability of the battery.

~.z j SAN ON0fRE-UN!! 2 8 3/4 8-2 s

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s

L l

l hPF-10-10 a

ATTACHMENT B

?

I i

I I.

t s

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..... ::8.. ?.

REACTIVITY CONTROL SYSTEMS PART LENGTH CFA INSERTION LIMITS LIMITING CONDITION FOR OPERATION 3.1.3.7 The position of the part length CEA group shall be:

a.

withdrawn to > 145" or; b.

restricted to prevent the neutron absorber section of the part length CEA group from covering the same axial segment (< 145") of the fuel assemblies for a period in excess of 7 EFPD out of any 30 EFPD period.

APPLICABILITY: MODES 1 and 2 ACTION:

With the neutron absorber scction of the part length CEA group covering any same axial segment of the fuel assemblies as specified in 3.1.3.7.b above, for a period exceeding 7 EFPD out of any 30 EFPD period, either:

a.

Reposition the part length CEA group to ensure no neutron absorber section of the part length CEA group is covering the same axial segment of the fuel assemblies within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , or b.

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 REQUIREMENTS

~

4.1.3.7 The position of the part length CEA group shall be determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

LP:4079 SAG ONOFRE-UQTlT 2 2/ 3 1-M

-TABLE 3.3-10

{l ACCIDENT MONITORING INSTRUMENTATION (CONTINUED)

REQUIRED MINIMUM NUMBER OF CHANNELS CHANNELS OPERABLE INSTRUMENT t

2 1

19.

Containment Area Radiation - High Range

20. Main Steam Line Area Radiation 1/ steam line N.A.

1 N.A.

21.. Condenser Evacuation System Radiation Monitor -

Wide Range 2

1 22.

Purge / Vent Stack Radiation Monitor Wide Range

1 N.A.

Pr9

23. Cold Leg HPSI Flow 1/ hot leg N.A.

24. Hot Leg HPSI Flow 1

I NOTES:

The two required channels are the Unit 2 monitor and the Unit 3 monitor.

s

.

ML20052H669

Text

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