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Proposed Tech Specs Changes Reducing Minimum Primary RCS Cold Leg Temp from 544 F to 535 F Between 70% & 100% Rated Thermal Power Levels
	ML20249B429
Person / Time
Site:	San Onofre
Issue date:	06/19/1998
From:	; SOUTHERN CALIFORNIA EDISON CO.
To:	;
Shared Package
ML20249B424	List: ML20249B423; ML20249B427; ML20249B429;
References
	NUDOCS 9806230088
	Download: ML20249B429 (67)
	v • d • e

_

PCN 491 Attachment A Existing Technical. Specifications SONGS Unit 2 i

9806230088 990619 PDR ADOCK 05000361 p

PDR L-__-_-_______-_____.

[.-__-__-_-________-_______-_-____-_________-_______

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 I=

3.4 REACTOR COOLANT SYSTEM (RCS) i.

3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits l'

LC0 3.4.1 RCS parameters for pressurizer pressure,' cold leg temperature, and RCS total flow rate shall be within the limits specified below:

a.

Pressurizer pressure 2 2025 psia and s 2275 psia; b.

RCS cold leg temperature (T,):

1.

For THERMAL POWER less than or equal to 30% RTP, 522*F s T s 558"F, e

2.

For THERMAL POWER less than or equal to 70% RTP and greater than 30% RTP, 535*F's T, s 558*F, 3.

For THERMAL POWER greater than 70% RTP, 544 F s T,

.s 558*F.

c.

RCS total flow rate 2 148E6Lbm/hrands177.6E6 Lbm/hr.

APPLICABILITY:

MODE 1.

NOTE------------------------

Pressurizer pressure limit does.not apply during:

a.

THERMAL POWER ramp > 5% RTP per minute; or b.

THERMAL POWER step > 10% RTP.

l ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME 1

A.

Pressurizer A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months pressure or RCS parameter (s) to flow rate not within limit, within-limits.

(continued) o SAN ON0FRE--UNIT 2 3.4-1 Amendment No. 127

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Recuired Action B.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months anc associated Completion Time of Condition A not met.

C.

RCS cold leg C.1 Restore cold leg 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months temperature not temperature to within limits, within limits.

4 D.

Required Action D.1 Reduce THERMAL 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated POWER to Completion Time of s 30% RTP.

Condition C not met.

SURVEILLANCE REQUIREMENTS i

SURVEILLANCE FREQUENCY l

SR 3.4.1.1 Verify pressurizer pressure 2 2025 psia and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months l

s 2275 psia.

l l

i SR 3.4.1.2 Verify RCS cold leg temperature:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1.

For THERMAL POWER less than or equal to 30% RTP, 522'F s Tc s 558 F, 2.

For THERMAL POWER less than or equal to 70% RTP and greater than 30% RTP, 535'F s Tc s 558*F, (continued) i SAN ONOFRE--UNIT 2 3.4-2 Amendment No. 127

i RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.2 (continued) 3.

For THERMAL POWER greater than 70% RTP, 544'F s Tc s 558'F.

NOTE--------------------------

Required to be met in MODE 1 with all RCPs running.

SR 3.4.1.3 Verify RCS total flow rate > 148E6 Lbm/ hour 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and s 177.6E6 Lbm/ hour.

i SAN ONOFRE--UNIT 2 3.4-3 Amendment No. 127

PCN 491 Attachment B I

Existing Technical Specifications SONGS Unit 3 l

RCS DNB (Pressure, Temperature, and Floc) Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS DNB-(Pressure, Temperature, and Flow) Limits LC0 3.4.1 RCS parameters for pressurizer pressure, cold leg temperature, and RCS total flow rate shall be within the limits specified below:

a.

Pressurizer pressure > 2025 psia and s 2275 psia; b.

RCS cold leg temperature (T ):

c 1.

For THERMAL POWER less than or equal to 30% RTP, 522*F s T s 558"F, c

2.

For THERMAL POWER less than or equal to 70% RTP and greater than 30% RTP, 535*F s T s 558*F, c

3.

For THERMAL POWER greater than 70% RTP, 544"F s T, s 558'F.

c.

RCS total flow rate > 148E6 tbm/hr and s 177.6E6 Lbm/hr.

APPLICABILITY:

MODE 1.

NOTE------------------------

Pressurizer pressure limit does not apply during:

a.

THERMAL POWER ramp > 5% RTP per minute; or b.

THERMAL POWER step > 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Pressurizer A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months pressure or RCS parameter (s)to flow rate not within limit.

within limits.

1 (continued)

SAN'ON0FRE--UNIT 3 3.4-1 Amendment No. 116 l

O RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action B.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time of Condition A not met.

C.

RCS cold leg C.1 Restore cold leg 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months temperature not temperature to within limits, within limits.

D.

Required Action D.1 Reduce THERMAL 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated POWER to Completion Time of s 30% RTP.

Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure 2 2025 psia and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s 2275 psia.

SR 3.4.1.2 Verify RCS cold leg temperature:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1.

For THERMAL POWER less than or equal to 30% RTP, 522'F s Tc s 558'F, i

2.

For THERMAL POWER less than or 70% RTP and greater than 30* '

5 s Tc s 558"F, (continued)

^

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.2 (continued) 3.

For THERMAL POWER greater than 70% RTP, 544'F s Tc s 558 F.

NOTE--------------------------

Required to be met in MODE 1 with all RCPs running.

SR 3.4.1.3 Verify RCS total flow rate > 148E6 Lbm/ hour 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and s 177.6E6 lbm/ hour.

)

l l

)

i l

SAN ONOFRE--UNIT 3 3.4-3 Amendment No. 116

D PCN 491 Attachment C Proposed Technical Specifications (Redline and Strikeout)

SONGS Unit 2 l

l RCS DNB (Pressure, Temperature, and Floa) Limits 3.4.1 i

l 3.4 REACTORCOOLANTSYSTEM(RCS) 3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits LC0 3.4.1 RCS parameters for pressurizer pressure, cold leg temperature, and RCS total flow rate shall be within the limits specified below:

)

1 a.

Pressurizer pressure 2 2025 psia and s 2275 psia; b.

RCS cold leg temperature (T ):

c 1.

For THERMAL POWER less than or equal to 30% RTP, 522*F s T s 558 F, EM'.!"E"?cr_r "ra ::,:';;'; v',cs"a! :Y/,,v'-

"'r

3. co so, smou sv>

r..,, sss,

m

,e a sso

32. For THERMAL POWER greater than t030% RTP, 5t4535*F s T, s 558 F.

c.

RCS total flow rate 2 14GEGLbiTi/in and a 177.GEG Lu' ni/in. 396,000fgpmi

' APPLICABILITY:

MODE 1.

NOTE------------------------

Pressurizer pressure limit does not apply during:

a.

THERMAL POWER ramp > 5% RTP per minute; or b.

THERMAL POWER step > 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Pressurizer A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months pressure or RCS parameter (s) to flow rate not within limit.

within limits.

(continued) l l

f I

SAN ON0FRE--UNIT 2 3.4 1 Amendment No tfi l-

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action B.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time of Condition A not met.

C.

RCS cold leg C.1 Restore cold leg 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months temperature not temperature to within limits, within limits.

D.

Required Action D.1 Reduce THERMAL 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated POWER to Completion Time of s 30% RTP.

Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure > 2025 psia and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s 2275 psia.

SR 3.4.1.2 Verify RCS cold leg temperature:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1.

For THERMAL POWER less than or equal to 30% RTP, 522'F s Tc s 558 F, 2.

Fcr THERMAL P0"ER less thar, cr equal to 70': RTP and greater than 30": RTP, 535"F

_ Tc _ 558"fr (continued) i I

SAN ON0FRE--UNIT 2 3.4-2 Amendment No. t27 l

l u_________

j

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.2 (continued)

'2.h for THERMAL POWER greater than 730%

RTP, M4535'F s Tc s 558*F.

NOTE--------------------------

Required to be met in MODE 1 with all RCPs running.

SR 3.4.1.3 Verify RCS total flow rate > 396,000 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months gpmHOEC Lbm/ hour end m 177.SES Lbm/ hour.

l l

SAN ON0FRE--UNIT 2 3.4-3 Amendment No. +27 i

I

!L

(

i l

i 1

PCN 491 i

1 Attachment D Proposed Technical Specifications (Redline and Strikeout)

SONGS Unit 3 i

{

L ___------ _---

RCS ONB (Pressure,-Temperature, and Flow) Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4' 1 RCS ONB (Pressure, Temperature, and flow) Limits LC0 3.4.1 RCS parameters for pressurizer pressure, cold leg temperature, and RCS total flow rate shall be within the limits specified below:

a.

Pressurizer pressure > 2025 psia and s 2275 psia; b.

RCS cold leg temperature (T,):

1.

For THERMAL POWER less than or equal to 30% RTP, 522*F s T, s 558"F, 2.

Fcr TllCR"AL P0"ER less than or equal to 70!i RTP and greater than 30": RTP, 535"F : T, m 550"F, 32.

For THERMAL POWER greater than 7030% RTP, 544535"F s T, s 558"F.

c.

RCS total flow rate 2 14SES Lbm/hr and a 177.SES Lbm/hr.396,0001gpmi APPLICABILITY:

MODE 1.

NOTE------------------------

i Pressurizer pressure limit does not-apply during:

a.

THERMAL POWER ramp > 5% RTP per minute; or b.

THERMAL POWER step > 10% RTP.

I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Pressurizer A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months pressure or RCS parameter (s)to flow rate not within limit.

within limits.

(continued)

SAN ONOFRE--UNIT 3 3.4-1 Amendment No. 446

RCS DNB (Pressure Temperature, and Flow) Limits 3.4.1 ACTIONS (continued)

CONDITION-REQUIRED ACTION COMPLETION TIME B.. Required Action 8.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and' associated Completion Time of Condition A not met.

C.

RCS cold leg C.1 Restore cold leg 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months temperature not temperature.to within limits, within limits.

D.

Recuired Action D.1

-Reduce THERMAL 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months anc associated POWER to Completion Time of s 30% RTP.

Condition C not' met.

1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure 2 2025 psia and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months l_

s 2275 psia.

l SR 3.4.1.2 Verify RCS cold leg temperature:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1.

For THERMAL POWER less than or equal to 30% RTP, 522'F s Tc s 558 F, 2.

For TllER".AL P0ER less ther. or equoi to 70*: RTP and greater than 30": RTP, 535T J

Tc : 558TT (continued) i l

SAN ON0FRE--UNIT 3 3.4-2 Amendment No. 4%

j i

RCS DNB (Pressure, Temperature, and Floa) Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR l3.4.1.2 (continued)

2. h For THERMAL POWER greater than 730%

RTP, 544535'F s Tc s 558'F.

NOTE--------------------------

Required to be met in MODE 1 with all RCPs running.

SR 3.4.1.3-Verify RCS total flow rate a 396,000 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months gpd140E6 L h/ hour er.d m 177.5ESLbm/ hour.

L l

SAN ON0FRE--UNIT 3 3.4-3 Amendment No. H 6

PCN 491 Attachment E Proposed Technical Specifications SONGS Unit 2 l

l

[

(

J

l*

RCS DNB (Pressure, Temperature, and Flow) Limits I.

3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS ONB (Pressure, Temperature, and Flow) Limits LC0 3.4.1 RCS parameters for pressurizer pressure, cold leg temperature, and RCS total flow rate shall be within the limits specified below:

a.

Pressurizer pressure > 2025 psia and s 2275 psia; b.

RCS cold leg temperature (T ):

c 1.

For THERMAL POWER less than or equal to 30% RTP, 522*F s T s 558 F, c

2.

For THERMAL POWER greater than 30% RTP, 535*F s Tc s 558 F.

c.

RCS total flow rate > 396,000 gpm.

APPLICABILITY:

MODE 1.

NOTE------------------------

Pressurizer pressure limit does not apply during:

a.

THERMAL POWER ramp > 5% RTP per minute; or b.

THERMAL POWER step > 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Pressurizer A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months pressure or RCS parameter (s) to flow rate not within limit, within limits.

(continued)

SAN ON0FRE--UNIT 2 3.4-1 Amendment No.

l l

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action B.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time of Condition A not met.

C.

RCS cold leg C.1 Restore cold leg 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months tem]erature not temperature to wit 11n limits.

within limits.

D.

Required Action D.1 Reduce THERMAL 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated POWER to Completion Time of s 30% RTP.

Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure 2 2025 psia and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s 2275 psia.

SR 3.4.1.2 Verify RCS cold leg temperature:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1.

For THERMAL POWER less than or equal to 30% RTP, 522 F s Tc s 558 F, 2.

For THERMAL POWER greater than 30% RTP, 535'F s Tc s 558 F.

j SAN ON0FRE--UNIT 2

'3.4-2 Amendment No.

L______---_.

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE--------------------------

Required to be met in MODE 1 with all RCPs running.

SR 3.4.1.3 Verify RCS total flow rate 2 396,000 gpm.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SAN ON0FRE--UNIT 2 3.4-3 Amendment No.

PCN 491

~

l l

Attachment F Proposed Technical Specifications SONGS Unit 3 i

F t

RCS DNB (Pressure, Temperature, and Flon) Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS DHB (Pressure, Temperature, and Flow) Limits LCO 3.4.1 RCS parameters for pressurizer pressure, cold leg temperature, and RCS total flow rate shall be within the limits specified below; a.

Pressurizer pressure > 2025 psia and s 2275 psia; b.

RCS cold leg temperature (T ):

c 1.

For THERMAL POWER less than or equal to 30% RTP, 522*F s T, s 558 F, 2.

For THERMAL POWER greater than 30% RTP, 535*F s T, s 558*F.

I c.

RCS total flow rate > 396,000 gpm.

APPLICABILITY:

MODE 1.

NOTE------------------------

Pressurizer pressure limit does not apply during:

I a.

THERMAL POWER ramp > 5% RTP per minute; or b.

THERMAL POWER step > 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME l

A.

Pressurizer A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months pressure or RCS parameter (s) to j

flow rate not within limit.

i within limits.

(continued) 1 1

1 SAN ON0FRE--UNIT 3 3.4 1 Amendment No.

1 L_._..__

RCS DNB (Pressure, Temperature, and Floc) Limits 3.4.1

~

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 1

B.

Required Action B.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time of Condition A not l

met.

C.

RCS cold leg C.1 Restore cold leg 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months temperature not temperature to i

within limits, within limits.

]

D.

Required Action D.1 Reduce THERMAL 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated POWER to Completion Time of s 30% RTP.

4 Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure 2 2025 psia and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s 2275 psia.

SR 3.4.1.2 Verify RCS cold leg temperature:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1.

For THERMAL POWER less than or equal to 30% RTP, 522'F s Tc s 558"F, 2.

For THERMAL POWER greater than 30% RTP, 535 F s Tc s 558 F.

SAN ONOFRE--!.: NIT 3 3.4-2 Amendment No.

_.__________________.--~J

RCS DNB (Pressure, Temperature, and Flow) Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

______.__...___..__.__.----NOTE--------------------------

Required to be met in MODE-1 with all RCPs running.

SR 3.4.1.3.

Verify'RCS total flow rate.2-396,000 gpm.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 4

1 l

l-SAN ON0FRE--UNIT 3-

'3.4-3 Amendment No.

f j '.

PCN 491 Attachment G Proposed Technical Specifications Bases s-SONGS Unit 2

. (For Information Only - Unit 3 will be the same as Unit 2) i

RCS DNB (Pressure, Temperature, and Flow) Limits B 3.4.1 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits BASES BACKGROUND These Bases address requirements for maintaining RCS pressure, temperature, and flow rate within limits assumed in the safety analyses. The safety analyses (Ref. 1) of normel operating conditions and anticipated operational occurrences and design basis accidents assume initial conditions within the normal steady state envelope.

The limits placed on DNB related parameters ensure that these parameters will not be less conservative than were assumed in the analyses and thereby provide assurance that the minimum departure from nucleate boiling ratio (DNBR) will meet the required criteria for each of the transients analyzed.

The LCO limits for minimum and maximum RCS pressures as measured at the pressurizer are consistent with operation within the nominal operating envelope and are bounded by those used as the initial pressures in the analyses.

The LC0 limits for minimum and maximum RCS cold leg temperatures are consistent with operation at the indicated power level and are bounded by those used as the initial i

temperatures in the analyses.

The LC0 limits for minimum and maximum RCS volumetric flow rates bounds-that are bounded by-thee-used as the initial flow rates in the analyses.

The RCS volumetric flow rate is not expected to vary during plant operation with all pumps running.

APPLICABLE The requirements of LC0 3.4.1 represent the initial SAFETY ANALYSES conditions for DNB limited transients analyzed in the safety analyses (Ref. 1).

Tne safety analyses have shown that transients initiated from the limits of this LC0 will meet the DNBR criterion of 2 1.31.

This is the acceptance limit for the RCS DNB parameters.

Changes to the facility that l

could impact these parameters must be assessed for their impact on the DNBR criterion.

The transients analyzed for include loss of coolant flow events and dropped or stuck control element assembly (CEA) events. A key assumption for the analysis of these events is that the core is operated (continued)

SAN ON0FRE--UNIT 2 B 3.4-1 Amendment No. 127

RCS DNB (Pressure, Temperature, and Flow) Limits

}

B 3.4.1 BASES r

APPLICABLE within the limits of LC0 3.1.7, " Regulating CEA Insertion SAFETY ANALYSES Limits";

LC0 3.1.8, "Part Length CEA Insertion Limits";

(continued)

LC0 3.2.3, " AZIMUTHAL POWER TILT (T,)"; and LC0 3.2.5, i

" AXIAL SHAPE INDEX (ASI)".

The safety analyses are performed over the following range of initial values: RCS l

pressure 2000 - 2300 psia, core inlet temperature 9tt-=

5GC^F (fei > 702 penerh--533 - 560 F (for s 702 pe h eiid

> 30% power), and 520 - 560 F (for s 30% power) and reactor vessel inlet coolant volumetric flow rateh95=-it0%.

The RCS Pressure, Temperature, and Flow limits satisfy Criterion 2 of the NRC Polic) Statement.

LC0 This LC0 specifies limits on the monitored process variables-RCS pressurizer pressure, RCS cold leg temperature-to ensure that the core operates within the limits assumed for the plant safety analyses. Operating within th",a limits will result in meeting the DNBR criterion in the event of a DNB limited transient.

The LC0 numerical values for pressure and temperature are given for the measurement location but have not been adjusted for instrument error. The uncertainties for pressure and temperature are accounted for in the CPC and COLSS overall uncertainty analyses. The RCS flow uncertainty must be applied to the valuer stated in this LCO.

APPLICABILITY In MODE 1, the limits on RCS pressurizer pressure, RCS cold leg temperature, and RCS flow rate must be maintained during steady state operation in order to ensure that DNBR criteria will be met in the event of an unplanned loss of forced coolant flow or other DNB limited transient.

In all other MODES, the power level is low enough so that DNBR is not a Concern.

A Note has been added to indicate the limit on pressurizer pressure may be exceeded during short term operational i

transients such as a THERMAL POWER ramp increase of > 5% RTP l

per minute or a THERMAL POWER step increase of > 10% RTP.

(continued)

{

SAN ON0FRE--UNIT 2 B 3.4-2 Amendment No. 127 May 29, 1997

RCS DNB (Pressure, Temperature, and Flow) Limits B 3.4.1 i

l BASES l

SURVEILLANCE SR 3.4.1.2 REQUIREMENTS (continued)

Since Required Action A.1 allows a Completion Time of 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to restore parameters that are not within limits, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Surveillance Frequency for cold leg temperature is sufficient to ensure that the RCS coolant temperature can be restored to a normal operation, steady state condition following load changes and other expected transient operations. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and to verify operation is within safety analysis assumptions.

SR 3.4.1.3 The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Surveillance Frequency for RCS total flow rate has been shown by operating experience to be sufficient to assess for potential degradation and to verify op? ration is within safety analysis assumptions.

The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Surveillance Frequency for RCS total flow rate is normally performed using the Core Operating Limits Supervisory System (COLSS) generated flow.

COLSS utilizes sensor inputs of RCP speed, RCP. differential pressure, cold leg temperature, and Pressurized pressure to calculate the volumetric flow through each RCP. Total RCS flow is then calculated by.COLSS as the sum of the flows of each of the four RCPs.-

When COLSS is out of service, RCS Mew Volumetris Flowrate is determined manually. An evaluation of the heat balance between primary and secondary plant powers is the preferred methodology to determine RCS Mew Volumetric Flowrate.

Another acceptable methodology is to determine RCS Men Volumetric Flowrate by performing an evaluation of the j

differential pressure across each RCP.

i (continued)

SAN ON0FRE--UNIT 2 B 3.4-5 Amendment No. 127

PCN 491 Attachment H UFSAR CHAPTER 15 ASSESSMENT

UFSAR CHAPTER 15 ASSESSMENT SUPPORTING PROPOSED TECHNICAL SPECIFICATION AMENDMENT This Attachment discusses the various UFSAR Chapter 15 engineering assessments performed in support of the proposed Technical Specification (TS) changes.

Specifically,1) the TS changes for the reduction in Reactor Coolant System cold leg temperature (RCS T u) at Power Levels > 70% rated thermal power (RTP)and2)theRCSflowchoange from Mass flow rate to Volumetric flow rate and removal of the upper RCS limit value.

The assessments performed demonstrate that the proposed TS LC0 values satisfy established Acceptance Criteria. The results of these assessments are presented in Table H.1 below.

Objective The objective of this assessment was to determine the impact of reducing the l

TS minimum T u on accident analyses presented in the Updated Final Safety co Analysis Report (UFSAR) (i.e., Chapters 6 and 15).

The minimum T u reduction co from the current value of 542*F to 533 F (which includes 2 F uncertainty),

resultsinanetreductionintheminimumT,E100%ofratedthermalpower of 9"F.

This temperature c

reduction is being applied to the 70% throug range.

In addition, this assessment addresses the impact of a change in the TS LC0 for RCS flow.

In particular,-the TS change consists of modifying the current minimum " mass" RCS flow to a minimum " volumetric" flow and removing the upper RCS limit value. The p RCS mass flow of 148x10,roposed TS change would replace the current TS minimum which corres)onds to 148x10'/ hour by a volumetric RCS flow of lbm 396,000 gpm lbm/hourat553*Fand2250psiaandalsoa removal of t1e upper limit of 177.6x10' lbm/ hour.

All of the UFSAR safety analysis events were assessed for San Onofre Units 2 and 3 with regard to the impact of the above stated minimum T u reduction and co flow rate change.

This assessment also addresses the impact of the above TS changes on the safety analysis events that are used to provide setpoints for the Core Operating Limit Supervisory System (COLSS) and the Core Protection Calculator l

System (CPCS).

The COLSS and CPCS setpoints are verified or modified at least once each fuel cycle to account for cycle-s 3ecific changes to core parameters.

COLSS uses on-line departure from nucleate ) oiling ratio (DNBR) calculations based on measured power, pressure, temperature, flow, and axial shape to assure that required thermal margin is maintained.

CPCS uses on-line DNBR calculations, based on inputs independent of the COLSS inputs, as part of its Low DNBR trip logic.

The use of on-line DNBR calculations by COLSS and CPCS causes the cycle-specific setpoints for many events to be insensitive to the values of T u and RCS flow that are assumed in the setpoint analyses (i.t.,

co for many events, the on-line adjustment of COLSS thermal margin and CPC DNBR basedonmeasuredT)u and measured RCS flow fully accounts for the variation l

in these parameters. Although the cycle-specific setpoints are insensitive to the values of T u and RCS flow that are assumed for many events, a review co of each event was performed.

This review identified those events for which the proposed TS changes would have no impact on the cycle-specific COLSS and CPCS setpoints and identified those events for which the proposed TS changes would potentially affect the cycle-specific setpoints.

For each event that is potentially affected, the Cycle 10 analysis will be performed consistent with the proposed TS changes.

7 H-1

l l

H.1 Discussion of UFSAR Chapter 15 Events Table H.1 shows the impact of the T o and flow specification changes on all relevant UFSAR Chapter 15 events.

Non-Mode 1 events (Sections 15.4.1.4, 15.4.1.5,15.4.3.1), Uncontrolled CEA Withdrawal from a Subcritical or Low Power Condition (Section 15.4.1.1), and Section 15.7 and 15.8 events are not j

relevant to this change and thus not included in this change.

Table H.1 Acronyms CFR

- Code of Federal Regulations CPC

- Core Protection Calculator CVCS

- Chemical and Volume Control System DNBR

- Departure from Nucleate Boiling LHR

- Linear Heat Rate LOCV

- Loss of Condenser Vacuum RCS

- Reactor Coolant System l

SBLOCA - Small Break Loss of Coolant Accident SG

- Steam Generator SONGS

- San Onofre Nuclear Generating Station UFSAR

- Updated Final Safety Analysis Report I

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l H.2 Detailed Evaluation of I pacted Events 15.2.1.3 Loss of Condenser Vacuum 15.2.2.3 Loss of Condenser Vacuum with Single Failure Eyaluation of Reduction in T,i, for Peak RCS Pressure 4

The peak RCS pressure criterion for this event is impacted by the reduction in Tcold. A reanalysis of this event for this criteria was performed and is presented in Attachment I.

15.5.1.1 Chemical and Volume Control System (CVCS) Malfunction 15.5.2.1 Chemical and Volume Control System Malfunction with Single Failure Evaluation of Reduction in T, for Peak RCS Pressure For the peak RCS pressure criterion, a sensitivity analysis had been performed to determine the impact of Tcoi,on the event.

It was determined that the impact of reducing the T from 560 F to 542 F resulted in a coi,

peak RCS pressure increase from 2592 psia to 2600 psia.

Based on this sensitivity analysis and linear extrapolation, peak pressure would increase by less than 10 psia (adding a factor of 2 for conservatism) as a result of lowering T,,i, to 533 F.

The limiting analysis (i.e., CVCS Malfunction + SF) was evaluated at 542'F and resulted in a peak RCS pressure of 2629 psia. Hence, the acceptance criterion for peak RCS pressure is not challenged as a result of reducing the minimum T/S Tcoi, from 544"F to 535"F.

15.6.3.3 Loss of Coolant Accident This section presents a summary of the assessment of the San Onofre Units 2 and 3 Emergency Core Cooling System (ECCS) performance analysis for potential impact of the proposed T/S changes.

The ECCS performance analysis consists of three individual components:

1.

Large Break Loss-of-Coolant Accident (LBLOCA) 2.

Small Break LOCA (SBLOCA) 3.

Post-LOCA Long Term Cooling (LTC)

These analyses are documented in UFSAR Sections 6.3.3, Performance Analysis and 15.6.3.3, Loss-of-Coolant Accident (LOCA).

The Inadvertent Opening of a Pressurizer Safety Valve (10PSV) event is also included in the assessment. The IOPSV event is documented in UFSAR Section 15.6.3.4.

The results of this event are bounded by those of the SBLOCA analysis and, consequently, the assessment for SBLOCA is applicable to the 10PSV event.

Tcold Specification Change Impact Large Break LOCA The San Onofre Units 2 and 3 LBLOCA ECCS performance Analysis of Record (A0R) was performed using a minimum Tcoi, of 530 F.

This bounds the new proposed minimum value of 533'F (i.e., the T/S value of 535 F minus a measurement uncertainty of 2 F).

I H - 14

______ _ ____ - _ _ _ A

Small Break LOCA

~

The San Onofre Units 2 and 3 SBLOCA ECCS performance analysis is not impacted by a reduction in the minimum T,y.

First, the SBLOCA analysis c

is not performed at the minimum T Furthermore, the peak cladding coi,.

temperature for the limiting SBLOCA occurs during a period of partial core uncovery hundreds of seconds after the start of the LOCA.

The amount of core uncovery and, consequently, the peak cladding temperature, is primarily determined by the competing effects of decay heat induced core boiloff and injection from the High Pressure Safety Injection pumps.

The initial T,y does not have a significant influence on the amount of core c

uncovery or the resultant peak cladding temperature.

Post-LOCA Long Term Cooling (LTC)

The San Onofre Units 2 and 3 Post-LOCA LTC analysis is not impacted by a reduction in the minimum T In general, an LTC analysis is begun after coio.

the core has been reflooded and, consequently, is not significantly impacted by normal operating conditions other than initial core power level (which determines the core decay heat that must be removed in the long term). Also, a reduction in T decreases the initial RCS stored coy energy that must be removed in the long term.

For these reasons, the proposed reduction in the minimum T,y does not c

impact the San Onofre Units 2 and 3 ECCS performance analysis.

Flow Specification Chance Imoact The conversion of the minimum RCS total flow rate from a mass flow rate to a volumetric flow rate does not impact the San Onofre Units 2 and 3 ECCS performance analysis.

This is because both the LBLOCA and SBLOCA analyses were performed at a minimum RCS volumetric flow rate that is consistent with the proposed TS conversion value (i.e., 396,000 gpm).

The post-LOCA LTC analysis is not impacted by the change since, as described abova for the reduction in minimum T the analysis is begun after the core has coi o,

been reflooded and, consequently, is not significantly impacted by full power operating conditions.

This is particularly true when the proposed change is essentially a change to the units used to express the operating condition and not a change to the actual value of the operating condition.

The San Onofre Units 2 and 3 ECCS performance analysis is not performed at the maximum RCS total flow rate and, consequently, there is no impact from removing the TS LC0 limit on the maximum value for the flow rate.

H - 15

PCN 491 Attachment I PROPOSED UFSAR SECTION 15.2.1.3 AND PROPOSED UFSAR SECTION 15.2.2.3 i

l

San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PIANT) 15.2.1.3 Loss of condenser vacuum 15.2.1.3.1 Identification of Causes and Frequency Classification The estimated frequency of a loss of condenser vacuum classifies it as a moderate frequency incident, as defined in reterence 1 of section 15.0.

A loss of condenser vacuum may occur due to failure of the circulating water system to supply cooling water, failure of the main condenser evacuation system to remove noncondensible gases, or excessive leakage of air through a turbine gland packing.

j In accordance with the direction given in Sections 15.0 and 15.0.7, additional information which completes the presentation of this event is provided in Section 15.10.2.1.3.

15.2.1.3.2 Sequence of Events and Systems Operation l

The turbine generator trip that occurs due to a loss of condenser vacuum would normally generate an immediate reactor trip signal from the turbine stop valves'(through unitized actuator pressure monitors).

If credit is not taken for reactor trip on turbine trip, reactor trip would occur as a result of high-pressurizer pressure.

The turbine bypass valves are unavailable

[

following a loss of condenser vacuum.due to the actuation of the condenser I

vacuum interlock on the turbine generator trip.

The feedwater pumps would trip on low suction pressure soon after turbine trip.

It is conservatively assumed that feedwater flow is terminated immediately after turbine trip.

The pressure increases in the primary and secondary systems following reactor trip are limited by the pressurizer and steam generator safety valves.

Following turbine trip, offsite power is available to. provide eeAC power to the auxiliaries..The case of loss of all normal eeAC power is presented in 15.2-4

San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PIANT) paragraph 15.2.1.4.

The operator Mmay cool the NSSS using manual operation of the auxiliary feedwater system and the atmospheric steam dump valves any time after the reactor trip occurs.

The analysis presented herein conservatively assumes that operator action is delayed until 30 minutes after the first indication of the event.

The consequences of a siig1U nQl f eiik_ tici& uf Qu m tiVU m vm.y v u m i.t m oy a um f viimwim lv5o v f b vouG u.m.

cm LossioflCondens.er Vacuum are diobu m d it.

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s b.~ vf - V s.uiono fmore : adverse than t'4e t vxuithose following a tLoss of eCondenser vVacuum NitP a'aingle failure which'ia described inil5,2;2;3. Therefore,1 refer to the

- inR1.a ebillimJ bui&da tion f

sequenceiof: eventsf and1results ofl the LOCV.with1 Single; Failure 1(Section 1522;2.3T"for eventusequenceldetails.

15.2.1.3.3 Core and System Performance 1

Thefcor'eTandTSystem-Performance;Followlng(a LossTofTCondenserivacuum arbV 7

no more Tdite rse ; thaf these ? following fai Loss 1 o f? condense r(vacuumlwith; Single Failure whichqis(described [inTparagraphl15.2.2i3;3.

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15.2-5

San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PLANT) 1_

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15.2.1.3.5 Radiological consequences The radiological consequences due to steam releases from the secondary system are less severe than the consequence of the inadvertent opening of the atmospheric dump valve discussed in paragraph 15.1.1.4.

15.2-9

e San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PLANT) 15.2.2.3 Loss of Condenser Vacuum with a Concurrent Sinale Failure of an Active Component i

15.2.2.3.1 Identification of causes and Frequency Classification i

The estimated frequency of a loss of condenser vacuum with a concurrent single i

failure of an active component classifies this incident as an-infrequent

)

incident as defined in reference 1 of section 15.0.

The cause of the loss of condenser vacuum is discussed in paragraph 15.2.1.3.1.

Various active component single failures were considered to determine which failure had the most adverse effect following a loss of condenser vacuum. The single failures j

considered were (1) a loss of all ac power on turbine trip, and (2) failure of

~

a pressurizer level measurement channel associated with the pressurizer level

]

control system.

The failure of a pressurizer level measurement channel produces the most adverse effect following a loss of condenser vacuum.

This failure is assumed to produce a false low level signal, resulting in activation of both standby charging pumps and the closing of the letdown control valve to its minimum flow area.

15.2.2.3.2 Sequence of Events and System Operation i

l The systems and reactor trip which operate following a loss of condenser vacuum with failure of a pressurizer level measurement channel are the same as those described in paragraph 15.2.1.3.2 following a loss of condenser vacuum.

In accordance with the direction given in Section 15.0 and 15.0.7, additional information which completes the presentation of this event is provided in j

Section 15.10.2.2.3.

Table 15.2-5 and Table 15.2-7 give a sequence of events that occur following a loss of condenser vacuum with concurrent failure of a pressurizer level measurement channel for peak RCS pressure and peak secondary pressure cases.

15.2-17 L

San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PLANT)

Table 15.2-5 SEQUENCE OF EVENTS FOR THE LOSS OF CONDENSER VACUUM EVENT WITH CONCURRENT SINGLE FAILURE - PEAK RCS PRESSURE CASE'"

l Time (sec)

Event Setpoint or Value l

0.0 closure of turbine stop valves on I

turbine trip due to loss of condenser vacuum 7.3 High pressurizer pressure trip 2,1372410 psia 8.6 condition occurs te Trip breakers open, yic seuii;u

)

9.5 sJ ay cel cs

(

v y x. u 10.3 Pressurizer safety valves begin to 2,5302575 psia open, psia te-+}

Main steam safety valves open 11331122 psia 10.'5

.3 CEAs begin to drop into core J

10;51

)

I 11.5 Maximum RCS pressure occurs 42,7502744 psia

[

11.~ 3

+fr-O Peak secondary pressure occurs

<1,210 psia 15.2 15 i L xit. a., vn oomim liquid a v l m. =-

" f4' Mr5 15.67 Pressurizer.s'afety.valvesfclose 2459 psia

)

g g--.

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15.2-18 1L______________..

San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PLANT)

Table 15.2-6 KEY PARAMETERS ASSUMED IN THE LOSS OF CONDENSEh VACUUM ANALYSIS WITH CONCURRENT SINGLE FAILURE - PEAK RCS PRESSURD CASE PARAMETER, UNIT VALUE Initial Core Power, MWt 3,478 j

Initial Inlet Coolant Temperature,

'F 5+2537"'

Initial volumetric-Cele Meso Flow Rate, W fft:1376i200 lbin/higpm Initial RCS Pressure, psia 2,000 Initial Steam Generator Pressure, psia 796 Moderator Temperature Coefficient, 10-' Ap/ 'F OW-0.3""

Fuel Temperature coefficient Multiplier 0.75 Minimum CEA Worth at Trip, % Ap

-6.0 pressurizer safety. valve ~-OpeninglSetpoint

( 3%

Tolerance Main" Steam l Safety Valve. Opening'Setpoint

+;:2%

Tolerance Steam Bypass Control System Inoperative Reactor Trip on Turbine Trip Inoperative Pressurizer Pressure Control System Inoperative Pressurizer Level Control System Single Failure is Assumed

(*}

The.; initial coze f inlet';. temperature l (Tem) wae :. varied ^from 532*F to1560'F to1 determine the '(Tem): which ' maximizes peak RCS pressure

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(LCS 3.1.100)L l

l 15.2-19

San Onofre 2&3 FSAR Updated I

DECREASE IN HEAT REMOVAL BY THL SECO!vDARY SYSTEM (TURBINE PLANT)

Table 15.2-7 1

SEQUENCE OF EVENTS FOR THE LOSS OF CONDENSER VACUUM EVENT PEAK SECONDARY PRESSURE CASE

i Time (sec)

Event Setpoint or Value 0.0 Closure of turbine stop valves on turbine trip due to loss of condenser vacuum 4.6

!4ain Steam Safety Valves Open 1133 psia l

r.5 High pressurizer pressure trip 2,437 psia condition occurs 8.4 Trip breakers open 8.7 Pressurizer safety valves open 2,538 psia 1

9.3 Maximum RCS Pressure occurs

< 2,600 psia j

9.5 CEAs begin to drop 12.5 Maximum Pressurizer Liquid Volume 1051 ft 3

occurs

)

13.0 Pressurizer safety valves close 2,410 psia I

l 14.2 Peak secondary pressure occurs

< 1,210 psia i*' The requence of event s p, esent ed is fut the peak W Cecondaly prescote ca e-which assumed a M.05V uet poi n t tolerance of+M.

The r+a k RC. I reesut e case reviewed and apptevm; t,y t he NM a s s um+-d a K:3V rat pv i nt tolerance of

+21.

f i

t l

l l

(

l 15.2-20 l

L____________________--

e San Onufre 2&3 FSAR Updated l

DECREASE IN HEAT REMOVAL BY THE i

SECONDARY SYSTEM (TURBINE PLANT) 1 i

l Table 15.2-8 KEY PARAMETERS ASSUMED IN THE LOSS OF CONDENSER VACUUM ANALYSIS PEAK SECONDARY PRESSURE CASE I

PARAMETER, UNIT VALUE Initial Core Power, MWt 3,478 Initial Inlet Coolant Temperature,

'F 560 Initial Core Mass Flow Rate, 10' lbm/hr 160.8 Initial RCS Pressure, psia 2,000 Initial Steam Generator Pressure, psia 965 Moderator Temperature Coefficient, 10~' /Q/*F 0.0 Fuel Temperature Coefficient Multiplier 0.75 M' ninium CEA Werth at Trip, % tw

-6.0 Steam Bypass Control System Inoperative Reactor Trip on Turbine Trip Inoperative Pressurizer Pressure Control System Automatic Pressurizer Level Control System Automatic j

1 i

15.2-21 l

San Onofre 2&3 FSAR Updated DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PLANT) 15.2.2.3.3 Core and System Performance 15.2.2.3.3.1 Mathematical Modgl.

tlc,omthmueticel nusnl uomd fu. s.vminmiivo vi vvi<

mud oyotca pmifv mmnce ai o ;dsnticml iv t ha t d m o m i Ls-J a n p o im 3ispL

~

15. 2.1. 2. 3.TheT NSSS response? to" A? loss of ? condenser vacuum 'with" concurrent single $ failure-was : simulated;usinglthe cESEc l computer program describedtin sectionll540; c

15.2.2.3.3.2 Innut Parameters and initial Conditions.

The input parameters and initial conditions used for evaluation of core and systems performance are listed.in Table 15.2-6 and Table 15.2-8 for peak RCS pressure and peak secondary pressure cases.

15.2.2.3.3.3 Results.

The results presented below are for the peak RCS pressure case,fwhich..assumedLa,MSSV;setpointjtolerance?of.f+2tiand peak secondary. pressure cases which assumed a MSSV setpoint tolerance of +3%.

The ps mi RCJ p msedim mnd pemL aucvudsiy pimeaum voamo u i m d and oppivumd by LLm I;RC m o e wumJ m I-133V..etpelni tvls.encm vi :n The dynamic behavior of important NSSS parameters following a loss of condenser vacuum with a concurrent failure of the pressurizer level control system is presented in figures 15.2-232 through 15.2-3+0 for the peak RCS pressure case.

The loss of steam flow due to closure of the turbine stop valves produces a rapid increase in the secondary pressure.

This produces a rapid decrease in the primary-to-secondary heat transfer, which causes a rapid heatup of the primary coolant.

The insurge to the pressurizer increases the pressurizer pressure producing a high-pressurizer pressure reactor trip condition at

+reSi6 seconds.

The CEAs begin dropping into the core at 9 e10.51 seconds.

The opening of the steam generator safety valves at 10.65 seconds and the pressurizer safety valves at er410.3 seconds combine with the decreasing core power due to reactor trip to rapidly reduce the primary and secondary pressures after reaching a maximum pressurizer pressure less than 2750 psia.

The pressurizer safety valves close at ++-915267 seconds.

Peak semvudmiy yi=.unim mnd peek pressurizer water volume are's calculated tn i

amem mtm ceum to be less than 1210 vo.m end leso ihon the volume which would 2

release liquid through the pressurizer safety valves,.copmciavmly.

PeaklsecondarpLpreisure isicalculaed~inla~sep hat' [ case'itolbeLlessLthan t

e

~

12101 psia; The steam generator valves continue to relieve steam to the atmosphere until the atmospheric steam dump valves are opened by operator action at 30 minutes.

The plant is then cooled to 350*F at which time shutdown cooling is initiated.

The maximum RCS and secondary pressures do not exceed 110% of design pressure following a loss of condenser vacuum with concurrent failure of the pressurizer level control system, thus. assuring that the integrity of the RCS and main steam system is maintained.

15.2.2.3.4 Barrier Performance 15.2.2.3.4.1. Mathematical Model.

The mathematical model used for evaluation of barrier performance is identical to that described in paragr4 h 15.2.1.3.315/2.2?3l3.

15.2-22 1

i

l*

l l

San onofre 2&3 FSAR Updated I

DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM (TURBINE PLANT) l l

15.2.2.3.4.2 Innut Parameters and Initial Conditions.

The input parameters l

and initial conditions used for evaluation of barrier performance are listed in Table 15.2-6.

l 15.2.2.3.4.3 Eesults.

Figures 15.2-29 29fand 15.2-24 30 give the pressurizer l

and steam generator safety valve flowrate versus time following a loss of condenser vacuum with concurrent failure of the pressurizer level l

measurement channel.

Until operator action is taken at 30 nunutes, l

the total steam release to atmotphere discharged through the steam generator safety valves has been no more than 50,100 100,_000.3 pounds. The operator would then begin a controlled NSSS cooldown at 75'F/hr by opening the atmospheric steam dp valves. After the 3-hour cooldown, the primary system will have reached an average temperature of 350*F at which point the shutdown cooling system may be placed in operation.

The total steam release to atmosphere during the course of this transient is 450,100 760,000 pounds.

l' 2.2.3.5 Radiological Consequences The radiological consequences of this event are less severe than the consequences of the inadvertent opening of an atmospheric dump valve discussed in paragraph 15.1.2.4.

I 1

l I

l 15.2-23 i

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100 90 l

80 1 -.

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70 m

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0 5

10 15 20 25 TIME, SECONDS I

1 SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 l

Updated Safety Analysis Report LOSS OF CONDENSER VACUUM

/

WITH CONCURRENT SINGLE FAILURE CORE POWER vs TIME Figure 1L.1-22

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10 15 20 25 TIME, SECONDS SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report LOSS OF CONDENSER VACUUM WITH CONCURRENT SINGLE FAILURE CORE AVERAGE HEAT FLUX vs TIME Figure 15 2-23

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2 i

$ 2400 8

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bx 1800-INCLUDES REACTOR COOLANT PUMP HEAD 1600 0

5 10 15 20 25 TIME, SECONDS SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report LOSS OF CONDENSER VACUUM WITH CONCURRENT SINGLE FAILURE REACTOR COOLANT SYSTEM PRESSURE vs TIME Figure 15.2-24 L

i 6-l 650 i

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Tin 525 l

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10 15 20 25 TIME, SECONDS SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report j

LOSS OF CONDENSER VACUUM WITH CONCURRENT SINGLE FAILURE I

COOLANT TEMPERATURES vs TIME Floure 15.2 25 l

4 900,

800 m

a Ea 700 S

e N

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N 600 2o s

a.

500 1

l 400 O

5 10 15 20 25 TIME, SECONDS SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report LOSS OF CONDENSER VACUUM W1TH CONCURRENT SINGLE FAILURE PRESSURIZER WATER VOLUME vs TIME Figure 15.2-26

t 1200 N

I 1100 1

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800 700 0

5 10 15 20 25 TIME, SECONDS l

SAN ONOFRE l

NUCLEAR GENERATING STATION l

UNITS 2 & 3 Updated Safety Analysis Report LOSS OF CONDENSER VACUUM WITH CONCURRENT SINGLE FAILURE STEAM GENERATOR PRESSURE vs TIME j

l Figure 15 2-27

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5 10 15 20 25 TIME, SECONDS SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report i

LOSS OF CONDENSER VAC'JUM WITH CONCURRENT SINGLE FAILURE SECONDARY LIQUID MASS vs TIME Figure 15.2-28 i

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l' l

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NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report

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LOSS OF CONDENSER VACUUM WITH CONCURRENT SINGLE FAILURE PRESSURIZER SAFETY VALVE FLOWRATE vs TIME Figure 15.2-29 i

i-

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1600 1400 h

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TIME, SECONDS SAN ONOFRE NUCLEAR GENERATING STATION UNITS 2 & 3 Updated Safety Analysis Report LOSS OF CONDENBER VACUUM WITH CONCURRENT SINGLE FAILURE MAIN STEAM SAFETY VALVE FLOWRATE vs TIME Figure 15.2-30

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