Text

Amends 74 & 62 to Licenses NPF-10 & NPF-15,respectively. Amends Revise Tech Spec 3/4.8.2 Re Dc Sources
	ML20246J032
Person / Time
Site:	San Onofre
Issue date:	08/25/1989
From:	; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20246J037	List: ML20246J032; ML20246N432;
References
	NUDOCS 8909050022
	Download: ML20246J032 (61)
	v • d • e

. _ _ _ _ _ _ _

c.

REISSUED 8/25/89 e.

I

' ELECTRICAL POWER SYSTEMS 3/4.8.2 0.C. SOURCES OPERATING' LIMITING CONDITION FOR OPERATION 3.8.2.1 As a minimum the following D.C. electrical sources shall be OPERABLE:

a.

125-volt battery bank A (28007), and its associated full capacity charger.

b.

125-volt battery bank B (28008), and its associated full capacity

charger, c.

125-volt battery bank C (2B009), and its associated full capacity charger.

d.

125-volt battery bank D (28010), and its associated full capacity charger.

APPLICABITY: MODES 1, 2, 3 aad 4.

2 ACTION:

a.

Witi one of the rcquired battery banks inoperable, restore the inoperable' battery bank to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 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 , b.

With orie of the require's full capacity chargers inoperable, demonstrate the OPERABILITY of its associated battery bank by performing Surveil-lance Requirement 4.8.2.1.a.1 within one hour, and at least orce per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereaft.er.

If any Category A limit.in Table 4.8-2 is not met, declare the Mtcery inoperable.

SURVEILLANCE REQUIREMENT 4.8.2.1 Each 125-volt battery bank and charger shall be demonstrated OPERABLE:

a.

At least once per 7 days by verifying that:

1.

The parameters in Table 4.8-2 meet the Category A limits, and 2.

The total battery terminal voltage is greater than or equal to 129-volts on float charge.

SAN ONOFRE-UNIT 2 3/4 8-9 AMENDMENT NO. 74 8909050022 890825 PDR ADOCK 05000361 P

PDC

REISSUED 8/25/89.

ELECTRICAL POWER SYSTEM SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per 92 days and within 7 days after a battery discharge with battery terminal voltage below 110-volts, or battery overcharge with battery terminal voltage above 150-volts, by verifying that:

1.

The parameters in Table 4.8-2 nieet the Category B limits, 2.

There is no visible corrosion at either terminals or connectors, or the connection resistance of these items is less than 150 x 10 6 ohms, and 3.

The average electrolyte temperature of ten connected cells is I

above 60 F.

c.

At least once per refueling interval

by verifying that:

l 1.

The cells, cell plates, and battery racks show no visual inaication of physical damage or abnormal deterioration, 2.

The cell-to-cell and terminal connections are clean, tight, and coated with anti-corrosion material, 3.

The resistance of each cell-to-cell and terminal connection is less than or equal to 150 x 10 6 nhms, and 4.

The battery charger will supply at least 300 amperes at 125-volts for at least 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

d.

At least once per refueling interval

by verifying that the l

battery capacity is adequate to supply and mainnin in OPERABLE status all of the actual or sittulated emergency loads for the design duty cycle when the battery is subjected to a battery service test.

e.

At least once per 60 months, during shutdown, by verifying that the battery capacity is at least 80% of the manufacturer's rating when subjected to a performance discharge test.

Once per 60 month interval, this performance discharge test may be performed in lieu of the battery service test required by Surveillance Requirement 4.8.2.1d.

f.

Annual performance discharge tests of battery capacity shall be given to any battery that shows signs of degradation or has reached 85% of the service life expected for the application.

Degradation is indicated when the battery capacity drops more than 10% of rated capacityfromitsaverageonpreviousperformancetests,orisbelow 90% of the manufacturer s rating.

The provisions of Technical Specification 4.0.2 are'not applicable.

For cycle 4 only, this surveillance interval may exctr d 24 lnonths but may not e

extend irore than 60 days beyond the last successful completion of Specifica-tion 4.8.2.1.b conducted prior to exceeding 24 months.

SAN ONOFRE-UNIT 2 3/4 8-10 AMENDMENT NO.74 l

l,

REISSUED 8/25/89 ELECTRICAL POWER SYSTEMS 3/4.8.2 D.C. SOURCES OPERATING LIMITING CONDITION FOR OPERATION 3.8.2.1 As a minimum the following D.C. electrical sources shall be OPERABLE:

a.

125-volt battery bank A (3B007), and its associated full capacity

charger, b.

125-volt battery bank 8 (3B008), and its associated full capacity charger.

c.

125-volt battery oank C (3B009) and its associated full capacity charger.

d.

125-volt battery bank D (3B010) and its associated full capacity charger.

APPLICABILITY:

MODES 1, 2, 3 and 4.

ACTION:

1 a.

With one of the required battery banks inoperable, restore the inoperable battery bank to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 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 , b.

With one of the required full capacity chargers inoperable, demonstrate the OPERABILITY of its associated battery bank by performing Surveil-lance Requirement 4.8.2.1.a.1 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter.

If any Category A limit in Table 4.8-2 is not met, declare the battery inoperable.

SURVEILLANCE REQUIREMENTS 4.8.2.1 Each 125-volt battery bank and charger shall be demonstrated OPERABLE:

a.

At least once per 7 days by verifying that:

1.

The parameters in Table 4.8-2 meet the Category A limits, and 2.

The total battery terminal voltage is greater than or equal to 129-volts on float charge.

I SAN ONOFRE-UNIT 3 3/4 8-9 AMENDMENT NO. 62

(*

l I

=

REISSUED B/25/89 ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per 92 days and within 7 days after a battery oischarge with battery terminal voltage below 110-tolts, or battery overcharge with battery terminal voltage above 150-volts, by verifying that:

.1.

The parameters in Table 4.8-2 meet the Category B limits, 2.

There is no visible corrosion at either terminals or connectors, or the connection resistance of these items is less than 150 x 10 6 ohms, and 3.

The average electrolyte temperature of ten connected cells is above 60 F.

c.

At least once per refueling interval

by verifying that:

I 1.

The cells, cell plates, and battery racks show no visual indication of physical damage or abnormal deterioration, 2.

The cell-to-cell and terminal connections are clean, tight, and coated with anti-corrosion material, 3.

The resistance of each cell-to-cell and terminal connection is less than or equal to 150 x 10 6 ohms, and 4.

The battery charger will supply at least 300 amperes at 125-volts for at least 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

d.

At least once per refueling interval

by verifying that the I

battery capacity is adequate to supply and maintain in OPERABLE status all of the actual or simulated emergency loads for the design duty cycle when the battery is subjected to a battery service test.

e.

At least once per 60 months, during shutdown, by verifying that the battery capacity is at least 80% of the manufacturer's rating when subjected to a performance discharge test. Once per 60 month interval, this performance discharge test.may be performed in lieu of the battery service test required by Surveillance Requirement 4.8.2.1d.

f.

Annual performance discharge tests of battery capacity shall be given to any battery that shows signs of degradation or has reached 85% of the service life expected for the application.

Degradation is indicated when the battery capacity drops more than 10% of rated capacity from its average on previous performance tests, or is below 90% of the manufacturer's rating.

"The provisions of Technical Specification 4.0.2 are not applicable.

For Cycle 4 only, this surveillance interval may exceed the 24 month refueling interval but may not extend more than 60 days beyond the last successful completion of the Specification 4.8.2.1.b survei+1ance-conducted prior to exceeding 24 months.

SAN ONOFRE-UNIT 3 3/4 8-10 AMENDMENT NO. 62

...u, P.EI550El E 25/33

. -[f[ '

'c, UNITED STATES i

NUCLEAR REGULATORY COMMISSION f.e e

t%A $wtNGTON, D. C. 205$5

"%..v....f July 28,1989 Decret hos. 50-361 and 50 362 Mr. Kenneth P. Baskin Mr. Gary D. Cotton Vice Presicent Senior Vice President Southern California Edison Company Engineering and Operations 2244 Walnut Grove Avenue San Diego Gas & Electric Company Fost Office Box 800 101 Ash Street Rosemead, California 91770 P.O. Box 1831 San Diego, California 92112 Gentlemen:

SUSJECT:

ISSUANCE OF AMENDMENT NO. 75 TO FACILITY OPERATING LICENSE NO.

NFF-10 AND Aw!NDwENT NO. 63 TO FACILITY OPERATING LICENSE NO.

NPF-15 SAN ONOFRE NUCLEAR GENERATING STATION, UNITS 2 AND 3 (TAC N05. 65001, 68002, 69840, 69841, 71054, 71055, 71172,

'71173,-71552, 715E3, 71930, 71931, 71932, 71933, 72868 AND 72869)

The Commission has issued the enclosed amendments to Facility Operating Licenses NFF-10 and NFF-15 for San Onofre Nuclear Generating Station, Units 2 and 3, respectively. The amendments consist of changes to the Technical Specifications in response to your applications dated April 26, October 11 October 24, November 7, and December 16, 1988; and January 16, January 20, and March 28, 1959, which were designated by Southern California Edison Company as PCNs 250, 252, 254, 256, 259, 260, 281 and 283. The amendments extend the interval for certain required 18 month surveillance tests in order to support the nominal 24 month fuel cycle.

The amendeents revise the following Technical Specifications (TS) to increase the interval for the 18 month surveillance tests to at least once per refuel-ing interval, which is defined as 24 months:

a.

TS 3/4.3.1,

" Reactor Protective Instrumentation."

b.

TS 3/4.3.2,

" Engineered Safety features Actuation System Instrumentation."

c.

TS 3/4.3.3.3,

" Seismic Instrumentation."

d.

TS 3/4.3.3.10, " Loose-Part Detection Instrumentation."

j e.

TS 3/4.6.4.3,

" Containment Dome Air Circulators."

f.

TS 3/4.7.3.2,

" Auxiliary Feedwater System."

g.

TS 3/4.7.3,

" Component Cooling Water System."

h.

TS 3/4.7.4,

" Salt Water Cooling System."

1.

TS 3/4.7.10,

" Emergency Chilled Water System."

j.

TS 3/4.7.8.1,

" Fire Suppression Water System."

k.

TS 3/4.8.1.1,

'AC Sources."

1.

TS 3/4.8.4,

" Electrical Equipment Protective Devices."

8L a #.

e(

u I

REISSUED S/25/69

!!ssrs. Bastin and Cotten July 28,1989 A ccpy of our related Safety Evaluatien is also enclosed. A copy of the Notice of Issuerice-for PCh 252, 256 and 281 is enclosed. The Notice of Issuar.ce for PChs 250, 254, 2E9, 260 and 283 will be included in the Commission's next-regular bimeekly Federal Register notice, Sincerely, g

~ _ = _

Donald E. Hickman, Project Manager Project Directorate V Division of Reactor Projects III, IV, Y and Special Projects Dffice of Nuclear Reactor Regulation Er. closures:

1.

Amendment ho. 75 to License No. NFF-10 2.

Amendntnt No. 53 to License No. NFF-15 3.

Safety Evaluation 4

hotice of issuance cc w/enciesures:

See next page m

4 I.

'~

REISSLED 8/25/E9 Mr.-Kenneth P. Saskin San Onofre Nuclear Ger.erating So.thern California Edison Comparty Station, Units 2 and 3 cC:

Charles R. Kocher, Esq.

Mr. Mark Medford Janes A. Beoletto, Esq.

Southern California Edison Company Southern California Edison Company 2244 Walnut Grove Avenue 2244 Walnut Grove Avenue P. O. Box 800 P. O. Ecx 800 Rosemead, California 91770 Rosemead, California 91770 Mr. Robert G. Lacy Orrick, Herrington & Sutcliffe Manager, Nuclear Department ATTN: David R. Pigott, Esq.

San Diego Gas & Electric Company 600 Montgomery Street P. O. Box 1831 San Francisco, California 94111 San Diego, California 92112 Alan R. Watts, Esq.

Dr. Gerard C. Wong, Chief Rourke & Woccruff Radiological Materials Control 7C1 S. Parker St. No. 7000 Section Crange, California 92668-4702 State Department of Health Services 714 P Street, Building fB Mr. Sherwin Harris Sacrasanto, California 95814 Resource Prcject Manager Public l'tilities Department Resident Inspector, San Onofre NPS City of Riverside e/o U.S. Nuclear Regulatory Cosnission 3900 Main Street Post Office Box 4329 Riverside, California 92522 San Clemente, California 92672 Mayor, City of San Clemente Mr. Charles B. Brinkman San Clemente, California 92672 Combustion Engineering, Inc.

12300 Twinbrook Parkway, Suite 330 Regional Administrator, Region V Rcckville, Maryland 20852 U.S. Nuclear Regulatory Cosmission 1450 Maria Lane / Suite 210 Mr. Roy Zimerman Walnut Cresk, California 94596 U.S. huclear Regulatory Comission Region V Chairman, Board of Supervisors 1450 Maria Lane, Suite 210 San Diego County Walnut Creek, California 94596 1600 Pacific Highway, Roce 335 San Diego, California 92101 Mr. Don Womeldorf Chief Environmental Mangement Branch Mr. F. B. Marsh, Project Manager California Department of Health Bechtel Power Corporation 714 P Street, Roca 616 P.O. Box 60360 Sacramento, California 95814 Terminal Annex Los Angeles, California 90060 (15)

_m__________2_

REISSUED 3/25/59 3

/*

'c, UNITED STATES

[

. }

NUCLEAR REGULATORY COMMISSION l

wasamotos.o c.rosss g

j s.

SOUTHERN CALIFORNIA EDISON COMPANY SAN DIEGO GAS AND ELECTRIC CollPANY THE CITY OF RIVERSIDE, CALIFORNIA THE CITY OF ANAHEIM, CALIFORNIA DOCKET NO. 50-361 sat. Ch0FRE NUCLEAR GENERAT!hG STATION, UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.75 License No. NPF-10 1.

The Nuclear Regulatory Comission (the Comissior.) has found that:

A.

The applications for amendment to the license for San Onofre Nuclear Generating Station, Unit 2 (the facility) filed by Southern Califernia Edison Company (SCE) on behalf of itself and San Diego Gas and Electric Company, the City of Riverside, Califorr.ia and the City of Anaheim, California (licensees) dated April 26, October II, October 24, Novesber 7, and Decerrber 16, 1988; and January 16 January 20 and March 28, 1989 comply with the standards and requirements of the Atomic Energy Act of 1954, as amenced (the Act), and the Cosmission's regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the applications.

the provisions of the Act, and the regulations of the Cosmission; C.

There is-reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health 1

and safety of the public, and (11) that such activities will be conducted in compliance with the Commission's regulations; D.

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

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and aF1 applicable requirements have been satisfied.

k ll

L'.

REISSLED 5,25,59 l

l l

2-2.

Accereir. gly, the license is amended by changes to the Technical Speci-ficatict.s as indicated in the attachment to this license amendment, and paragraph 2.C(2) of Facility Operating License No NPF-10 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A, and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 75, are hereby incorporated in the license. SCE shall operate the facility in accordance with the Technical Specifications and the Environmental Protecticn Flan.

3.

This literse amendment is effective as of the dete of its issuance and nust be fully implemented no later than 30 days from the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION George W. Knig

n. Director Project Directorate V Divistor. of Reactor Projects 111, IV, V and Special Projects

Attachment:

Changes to the Technical Specifications Date of Issuance: July 28, 1989 ep

_a

j REISSUED 8/26/a9 i

4

_4TTACHMENT TO LICENSE AMENDMENT NO.75 FACILITY OPERATING LICENSE NO. NPF-10 DOCKET NO. 50-361 Revise Appendix A Technical Specifications by removing the pages identified belew and inserting the enclosed pages. The revised pages are identified by amendment number and contain marginal lines indicating the area of change.

Also enclosed are the following everleaf pages to the amended pages.

AMENDMEliT PAGE OVERLEAF PAGE 3/4 3-1 3/4 3-2 2/4 3-13 3/4 3-14 3/4 3 44 3/4 3-43 3/4 3-75 3/4 3-76 3/4 6-28 3/4 6-27 3/4 7-5 3/4 7-4 3/4 7-11 3/4 7-12 3/4 7-27 3/4 7-28 3/4 7-37 3/4 7-36 3/4 6-2 3/4 6-3 3/4 8-4 3/4 8-16 3/4 8-15 3/4 8-31 3/4 6-32 W

O

m--------

s 4,.,

s 1

REISSUED 5/25/69 I3/4'.3' INSTRUMENTATION i3/4.3.1 REACTOR PROTECTIVE INSTRUMENTATION.

LIMITING CONDITION FOR OPERATION 3.3.1.As a. minimum, the reactor. protective instrumentation' channels and

! bypasses of Table'3.3-1 shall be OPERABLE with RE3PONSE TIMES as shown in

. Table'3.3-2.

APPLICABILITY:

As shown in Table 3.3-1.

ACTION:

'As shown in: Table 3.3-1.

SURVEILLANCE REQUIREMENTS

4. 3.1 '.1 Each reactor protective instrumentation channel-shall.be demonstrated

- OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations for the MODES'and at the frequencies shown

.in Table 4.3-1.~

1:

4.3.1.2 The logic for'the bypasses shall be demonstrated OPERABLE prior to l

each reactor startup unless performed during the. preceding 92 days. The total bypass function shall'be demonstrated OPERABLE at least once per refueling interval.for each channel affected by bypass operation.

The provisions of

. Technical Specification 4.0.2 are not applicable.

4.3.'1.3. The REACTOR TRIP SYSTEM RESPONSE TIME of each reactor trip function shall be. demonstrated to be within its limit at least once per 18 months.

Each test shall-include at-least one channel-per function such that all'.

channels are tested at'least once every N times 18 months.where N is the total number of redundant channsis in a specific reactor trip function as shown in

-the " Total No. of Channels" column of Table 3.3-1.

4.3.1.4 The isolation characteristics of each CEA isolation amplifier and each optical isolator for CEA Calculator to Core Protection Calculator data

. transfer shall be verified at least once per 18 months during the shutdown per the following tests:

a.

For the CEA porition isolation amplifiers:

1.

With 120 volts AC (60 Hz) applied for at least 30 f.econds across the output, the reading on the input does not exceed 0.015 volts DC.

SAN ONOFRE - UNIT 2 3/4 3-1 AMENDMENT NO. 75 l

INSTRUMENTATION SURVEILLANCE REQUIREMENTS (Continued) 2.

With 120 volts AC (60 Hz) applied for at least 30 seconds-across the input, the reading on the output does not exceed 8 volts DC.

b.

For the optical isolators:

Verify that the input to output insulation resistance is gt-eater than 10 megohms when tested using a megohmmeter on the 500 volt DC range.

~

4. 3.1. 5 The Core Protection Calculator System shall be determined OPERABLE at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that less than three auto restarts have occurred on each calculator during the past 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.3.1.6 The Core Protection Calculator System shall be subjected to a CHANNEL FUNCTIONAL TEST to verify OPERABILITY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of receipt of a High CPC Cabinet Temperature alarm.

l l

i l

l mp SAN ONOFRE-UNIT 2 3/4 3-2 l

- REISSUED 8/25/S9 INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMIT 1 6 CONDITION FOR OPERATION 3.3.2 The Engineered Safety."eature Actuation System (ESFAS) instrumentation channels and bypasses shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consist o t with the values shown in the Trip Setpoint column of Table 3.3-4 and with :SPONSE TIMES as shown in Table 3.3-5.

APPLICABILITY:

As shcsn in Table 3.3-3.*

ACTION:

a.

With an ESFAS instrumentation channel trip setpoint less conservative than the value snown in the Allowable Values column of Table 3.3-4, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trio retpoint adjusted consistent with the Trip Setpoint value.

b.

With an ESFAS instrun.intation channel inoperable, take the ACTION shown in Table 3.3-3.

' SURVEILLANCE REQUIREMENTS 4.3.2.1 -Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the performance'of the CHANNEL CHECK, CHANNEL CAI mo;.fl0N and CHANNEL FUNCTIONAL TEST operations for the MODES and at the frequencies shown.in Table 4.3-2.

4.3.2.2 The logic for the bypasses shall be demonstrated OPERABLE during the at power CHANNEL FUNCTIONAL TEST of chanrels affected by bypass operation.

The total bypass function shall be demonstrated OPERABLE at least once per refueling interval for each channel affected by bypass operation. The provisions of Technical Specification 4.0.2 are not applicable.

4.3.2.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months.

Each test shall include at least one channel per function such that all channels are tested at least once every N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the

" Total No. of Channels" Column of Table 3.3-3.

"See Special Test Exception 3.10.5 SAN ONOFRE-UNIT 2 3/4 3-13 AMENDMENT NO.75

,4 1

_a

' ~ ' '

S N

0 0

O 0

0 0

1 1

I 1

1 1

~,

1 C

A 8

9 9

9 8

9 9

8 8

9 9

E 4

)

4 4

L a

l S

(

l AE 3

3 3

CD O

I LM 2

2 2

N P

0 P

A l

I 1

1 1

1 i

A T

N

[

2 2

M l

f f

i 5E o

o o

o R

Mt T

L S

UI B t

s s

s N

MNA s

t t

t NR e

e e

e I

I NAI s

s H'

li l' s

s I

MCO 2

3 3

3 2

3 3

2 2

3 1

1 3

5 Y

S 3

N 2

2 2

2 0

L 3

1 S

f f

LP o

o o

o 1

3 A

EI U

NR t

t t

t E

I NT e

e

)

e e

L C

A s

s b

s s

B A

li0

(

A C1 2

2 2

1 I

T I

2 2

I i

2 2

R l

l l

A 2

2 2

2 L

f

. S f

f f

f OI o

o o

o Y

NE T

N s

s s

s E

LN t

t t

t AA e

e I

l s

s s

s A

T l e

e S

OC T

2 4

4 4

2 4

4 2

2 4

4 D

F f

O R

)

E S

E A

N

)

I I

s e e

) s e C

e G

) n r r

n S n r n

(

r n

N S o u u

o A o u o

u o

E At s s

i St s

i Np p

s i

I t s

s t

Ct s

t Oi i

s t

Su e e

a

( u e a

I r r

e a

(B r

r u

B r u

TT T) r u

P P

t Y

Ph t A(

( c P t

Np c

Ap g c L

(

c Oi t r

A Ri ti A

OS S

t A

I r n e

P r nH SA) A) n TT e

z c

ST e

c II s I s e c

C(

m i

i

(

m-i Cn Sn m i

E n

r t c T

n t c T

o o n t c T

Jl ih u

ai Nl ih ai Nl t l t ih ai Na ag sw mg E a ag mg E at at ag mg I

N u

ti so oo Nu ti oo I

MnB uu uu ti oo U

n nH eL tL N n nH tL nB nH tL Ya o r

u I a o u

I a a

o u

L TM C P

A AM C A

AM M

C A

A E

T T

N F

O A.

N N

I S a.

b.

O. b c

C a.

O c

d Ca b

c d

T CN 4

U F

1 2

3

.vE EQM&* ' N w} Yg ggI*g =? =

1 l

)

i I[

3 i

l TABLE 3.3-7 SEISMIC MONITORING INSTRUMENTATION Minimum Measurement Instrument Instruments & Sensor Locations Rance Operable 1.

Triaxial Time-History Strong Motion Accelerometers a.

Steam Generator Base Support

-2 to +2g I

b.

Pressurizer Base Support

-2 to +2g I

c.

Reactor Coolant Pump

-2 to +2g I

d.

Containment Base in Tendon Gallery

-2 to +2g i

e.

Containment Operating Level

-2 to +2g I

f.

Unit #1 Free Field

-1 to +1g 1

g.

Control Building Basement

-2 to +2g I

h.

Control Building Roof

-2 to +2g 1

1.

Safety Equipment Building Base Slab

-2 to +2g 1

j.

Safety Equipment Building Piping Support

-2 to +2g I

k.

Radwaste Building Equipment Support

-2 to +2g 1

2.

Triaxial Peak Reading Accelerographs a.

Control Building-Control Room

-2 to +2g 1

b.

Control Building Base

-2 to +2g 1

c.

Top of Containment Structure

-5 to +5g I

d.

Reactor Coolant Piping

-2 to +2g 1

3.

Seismic Triggers a.

Containment Base in Tendon Gallery

+0.005 to +0.05g 1

b.

Containment Operating Level

+0.005 to +0.05g 1

4.

Seismic Switches a.

Steam Generator Base Support Set pt. 0.45 Horz/0.30 Vert.

1**

b.

Containment Base in Tendon Gallery Set pt. 0.40 Horz/0.50 Vert.

1**

5 Seismic Alarm Annunciator (4a & 4b are sensors) a.

Control Room Panel L-167 6.

Peak Shock Recorder a.

Containment Base in Tendon Gallery 2 to 25.4 Hz 1**

1.6 to 90g 7.

Peak Shock Annunciator 2 to 25.4 Hz 1

1.6 to 90g a.

Control Room Panel L-167 WRWith control room indication SAN ONOFRE-UNIT 2 3/4 3-43 I

REISSUED 8/25/89~

TABLE 4.3-4 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL FUNCTIONAL FUNCTIONA INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST 1.

Triaxial Time-History Strong Motion Accelerometers a.

Steam Generator Base Support M*

(1)

SA b.

Pressurizer Base Support M*

(1)

SA c.

Reactor Coolant Pump M*

(1)

SA d.

Containment Base in Tendon Gallery M*

(1)

SA e.

Containment Operating Level M*

(1)

SA f.

Control Building Basement M*

(1)

SA g.

Control Building Roof M*

(1)

SA h.

Safety Equipment Building Base M*

(1)

SA i.

Safety Equipment Building Piping Support M*

(1)

SA j.

Radwaste Building Equipment Support M*

(1)

SA-2.

Triaxial Peak Recording Accelerographs a.

Control Building-Control Room N/A (1)

N/A b.

Control Building Base N/A (1)

N/A c.

Top of Containment Structure N/A (1)

N/A d.

Reactor Coolant Piping N/A (1)

N/A 3.

Seismic Triggers a.

Containment Base in Tendon Gallery M

(1)

SA b.

Containment Operating Level M

(1) 5/U**'

4.

Seismic Switches a.

Steam Generator Base Support M

(1)**

SA**

b.

Containment Base in Tendon Gallery M

(1)**

SA**

. 5.

Seismic Alarm Annunciators (4a & 4b are sensors) a.

Control Room Panel L-167 M

(1)

SA 6.

Peak Shock Recorder a.

Containment Base in Tendon Gallery N/A (1)**

N/A 7.

Peak Shock Annunciator a.

Control Room Panel L-167 N/A (1)**

N/A

Except seismic trigger

- With Control Room indication

- - Need not be performed more frequently than once per 6 months.

(1) Once per refueling interval. The provisions of Technical Specification 4.0.2 are not applicable.

SAN ONOFRE-UNIT 2 3/4 3-44 AMENDMENT NO. 75 il

--- ~ -

~

~l f*

REISSUED S/25/E9

~ INSTRUMENTATION I

LOOSE-PART~ DETECTION INSTRUMENTATION 1

LIMITING CONDITION FOR OPERATION-

'l 13.3.3.10 The loose part detection system shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTION:

a.

With one o'r more loose part detection system channels inoperable for more than 30' days, prepare and submit'a Special Report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining tae cause 'of the malfunction. and the plans-for. restoring

.the channel (s) to OPERABLE status.

.b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3'.3.10 'Each chaniel of the loose part detection system shall be demonstrated OPERABLE by performance of a:

a.

CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , b.

CHANNEL FUNCTIONAL TEST at least once per 31 days, and

~c.

CHANNEL CALIBRATION at least once per refueling interval.

l SAN ONOFRE-UNIT 2 3/4 3-75 AMENDMENT NO. 75 l

1 INSTRUMENTATION 3/4.3.4 TURBINE OVERSPEED PROTECTION LIMITING CONDITION FOR OPERATION 3.3.4 At least one turbine overspeed protection system shall be OPERABLE.

APPLICABILITY: MODES 1, 2* and 3.*

ACTION:

a.

With one stop valve or one control valve per high pressure turbine steam lead inoperable and/or with one reheat stop valve or one reheat intercept valve per low pressure turbine steam lead inop-erable, restore the inoperable valve (s) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or close at least one valve in the affected steam lead or isolate the turbine from the steam supply within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With the above required turbine overspeed protection system otherwise inoperable, within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months isolate the turbine from the steam supply.

SURVEILLANCE RE0VIREMENTS 4.3.4 The above required turbine overspeed protection system shall be demonstrated OPERABLE:

a.

At least once per 7 days by cycling each of the following valves through at least one complete cycle from the running position.

1.

Four high pressure turbine stop valves.

2.

Four high pressure turbine control valves.

3.

Six low pressure turbine reheat stop valves.

4.

Six low pressure turbine reheat intercept valves.

b.

At least once per 31 days by direct observation of the movement of each of the above valves through one complete cycle from the running position.

c.

At least once per 18 months by performance of a CHANNEL CALIBRATION on the turbine overspeed protection systems, d.

At least once per 40 months by disassembling at least one of each of the above valves and performing a visual and surface inspection of valve seats, disks and stems and verifying no unacceptable flaws or corrosion.

"With any main steam line isolation valve and/or any main steam line isolation valve bypass valve not fully closed.

SAN ONOFRE-UNIT 2 3/4 3-76 AMINDMENT No. 31

.+

RE '..* 3 E ) 6,' 3.',' f ;

CONT!.]NUENT SYSTEMS ELECTRIC HYDROGEN RECOM21NERS LIMITING CONDITION FOR OPERATION 3.6.4.2 Two independent containment hydrogen recombiner systems shall. be OPERABLE.

APPLICABILITY: MODES I and 2.

ACTION:

With one hydrogen recombiner system inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least NOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.6.4.2 Eacn hydrogen recombiner system shall be demonstrated OPERABLE:

At least once per 6 months by verifying, during a recombiner system a.

functional test, that the minimum heater sheath temperature increases to reaching 700' greater than or equal to 700*F within 90 minutes.F, increa Upon 2 minutes and verify that the power meter reads greater than or equal to 60 kw.

b.

At least once per refueling interval by:

1.

Performing a CHANNEL CALIBRATION of all recombiner instrumentation and control circuits.

2.

Verifying through a visual examination that there is no evidence of abnormal conditions within the recombiner enclosure (i.e., loose wiring or structural connections, deposits of foreign materials,.etc.), and 3.

Verifying the integrity of the heater electrical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than or equal to 10,000 ohns.

SAN ONOFRE-UNIT 2 3/4 6-27 AMENDMENT NO. 73 1

l t

L RE155UED'8fi5/89 i

CONTAINMENT SYSTEMS CONTAINMENT DOME AIR CIRCULATORS l

L LIMITING CONDITION FOR OPERATION 1

l 3.6.4.3 Two independent dome air circulator trains shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTION:

With one dome air circulator train inoperable, restore the inoperable train to OPERABLE status within 30 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 .

SURVEILLANCE REQUIREMENTS 4.6.4.3 Each dome air circulator train shall be demonstrated OPERABLE:

At least once per refueling interval by starting each train on a a.

CCAS signal and verifying that the system operates for at least 15 minutes.

b.

At least once per refueling interval by verifying a system flow rate of at least 37,000 cfm.

I SAN ONOFRE-UNIT 2 3/4 6-28 AMENDMENT NO. 7E 1*

__._.____,__m__.--__-______.__e___mW

_________-___m__.__.____

i.;*

,o

'S PLANT SYSTEMS AUXILIARY FEEDWATER-5YSTEM LIMITING' CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater pumps and associated flow pa*hs shall be OPERABLE with:

Two motor-dri$en auxiliary feedwater pumps, each capable o,.f,being a.

-powerec from separate emergency busses, and b.

One steam turbine-driven auxiliary feedwater pump capable of being powered from an OPERABLE steam supply system.

ADPLICAEILITY: MODES 1, 2 and 3.

ACTION:

a.

With one auxiliary feecwater pump inoperable, restore the required auxiliary feedwater pumps 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 SHUT 00WN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With two auxiliary pumps inoperable, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c.

With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary feecwater pump to OPERABLE status as soon as possible.

SURVEILLANCE REQUIREMENTS i

4.7.1.2.1 Each auxiliary feedwater pump shall be demonstrated OPERABLE:

a.

At least once per 31 days by:

1.

Testing the turbine driven pump and bcth motor driven pumps pursuant to Specification 4.0.5.

The provisions of Specification 4.0.4 are not applicable for the turbine driven pump for entry into MODE 3.

2.

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.

3.

Verifying that both manual valves in the suction lines from the primary AFW supply tank (condensate storage tank T-121) to each AFW pump, and the manual discharge line valve of each AFW pump are locked in the open position.

SAN DNGFRE-UNIT 2 3/4 7-4 AMENDMENT NO. 25 l

y

c..

4 REISSUED 8725/89 PLANT SYSTEMS w

SURVEILLANCE REQUIREMENTS-(Continued)

,4 Verifying that the AFW piping is full of water by venting the accessible discharge piping high points.

b.

At least once per refueling interval during shutdown'by:

l' 1

1.

Verifying that each automatic valve in the flow path actuates to its-correct position upon receipt of an EFAS test signal.

i:

2.

Verifying that each pump starts automatically upon receipt of h

an EFAS test signal.

4.7.1.2.2 The auxiliary feedwater system shall be demonstrated OPERABLE-prior-

'to entering MODE 2 following each COLD SHUTDOWN by performing a flow test to verify-the normal flow path f rom the primary AFW supply tank (condensate stor-age tank T-121) through each auxiliary feedwater pump to its associated steam generator.

em SAN ONOFRE-UNIT 2 3/4 7-5 AMENDMENT NO. 75

___..m_..

F%*:

. REISSUED _8/25/39' t

PLANT SYSTEMS-3/4.7.3 COMPONENT COOLING WATER SYSTEM LIMITINGCONDITIONFfROPERATION 3.7.3 At least'two independent component cooling water' loops shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With only one component cooling water. loop OPERABLE, restore at least two

' loops 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 COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.3 At least two component cooling water loops shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power operated or automatic) servicing safety related equipment that

.is not locked, sealed, or otherwise secured in position, is in its correct position.

b.

At least once per refueling interval during shutdown, by verifying that each automatic valve servicing. safety-related equipment actuates to its correct position and each component cooling water pump starts automatically on an SIAS test signal.

SAN'ONOFRE-UNIT 2 3/4 7-11 AMENDMENT NO.75 l

REISSUED 8/25/89-I-

PLANT SYSTEMS 3/4.7.4 SALT WATER COOLING SYSTEM i

LIMITING CONDITION FOR OPERATION 3.7.4 At least two independent salt water cooling loops shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3 and '

1 ACTION:

With only one salt water cooling loop OPERABLE, restore at least two loops to 0PERABLE 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 COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

I SURVEILLANCE REQUIREMENTS l'

l 4.7;4 At least two salt water cooling loops shall be demonstrated OPERABLE:

At'least once per 31 days by verifying that each valve (manual, a.

power operated or automatic) servicing safety related equipment that-is not locked, sealed or otherwise secured in position, is in its correct position.

b.

At least once per refueling interval during shutdown, by verifying that each automatic valve servicing safety-related equipment actuates to its correct position and each salt water cooling pump starts automatically on an SIAS test signal.

l l

SAN ONOFRE-UNIT 2 3/4 7-12 AMENDMENT.NO. 75 I

11

~

REISSUED 8/25/89 PLANT SYSTEMS SURVEILLANCE REQUIREMENTS 4.7.8.1.1 The fire suppression water system shall be demonstrated OPERABLE:

At least once per 7 days by verifying the contained wate supply-a.

volume.

b.

At least once per 31 days on a STAGGERED TEST BASIS by starting each electric motor driven pump and operating it for at least 15 minutes on recirculation flow.

c.

At least once per 31 days by verifying that each valve (manual, oower operated or automatic) in the. flow path is in its correct position.

d.

At least once per 12 month:; by cycling each testable valve in the flow path through at least one complete cycle of full travel.

e.

At least once per 18 months by performinn a system functional test which includes simulated automatic actuatson of the system through-out its operating sequence and:

1.

Verifying performance of the fire pumps as follows:

a.

Diesel engine drive pump develops at least 2500 gpm at a system head of 283 feet, b.

Electric motor driven pumps each develop at least 1500 gpm at a 'p tem head of 289 ft.

2.

Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full travel,* and I

3.

Verifying that each fire suppression pump starts (sequentially) to maintain the fire suppression water system pressure greater than or equal to 95 psig.

f.

h least once per 3 years by performance of a system flush.

Refueling interval for those plant areas that art inaccessible during non refueling operations.

SAN ONOFRE-UNIT 2 3/4 7-27 AMENDMENT NO. 75 j

E j L

Lo

l[

o.

PLANT SYSTEMS 5'. :.. E! L L C E E :d E"E'.~ 5 C:- i nued At least once per 3 years ty performing a flow test of the system in

~

accorcamce -itn Chacter 5, Section il of the Fire Protection g.

12th Ecitien, ;. lished by the National Fire Protection

Hanc0cck, Asscciatien.

2.7.8.12~ The fire pero diesel engine stall te ceecnstrated CPE?>E'.E:

At least ence per 31 cays Oy verifying:

a.

The diesel fuel oil day storage tank contains at least 1.

225 gallens of feel, and T e ciesel starts ' :

arcient (cn:i-icns arc cperates 'er at 2

least 30 minutes on recirculate:n ficw.

At least en:e per 92 cays Oy verifying tnat a saeple of diesel fuel from the fuel storage tank, cutained in acccrdance witn ASTM-D270-1975, b.

0975-1977 is witnin the acce;tatie limits specified in Table 1 of ASTM when checked for viscesity, water and sediment.

At least once per 18 genths during shutdown, by subjecting the diesel to an ins;ection in accordance with procedures prepared in c.

conjunction with its manufacture'r's recommendations for the class of service.

The fire pump diesel starting 24-volt battery barsk and charger 4.7.8.1.3 shall de demonstrated OPERAELE:

At least cnce per 7 days by verifying that:

a.

The electrolyte level of each battery is above tne plates, and 1.

The overall battery voltage is greater than or equal to l

l 2.

24 volts, At least once per 92 days by verifying that the specific gravity is b.

appropriate for continued service of the battery.

At least once per 18 months by verifying that:

c.

The batteries, cell platvs and battery racks show no visual

. indication of physical damage or abnormal deterioration, and i

1.

The battery-to-battery and terminal connections are clean, l

tight, free of corrosion, and coated with anti-corrosion 2.

material.

3/4 7-28 SAN ONOFRE-UNIT 2 lu

i PLANT SYSTEMS 3/4.7.10 EMERGENCY CHILLED WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.10 Two independent emergency chilled water systems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With only one emergency chilled water system OPERABLE, restore the a.

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 haurs.

b.

With only one emergency chilled water system OPERABLE:

1.

Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months verify that the normal HVAC system is providing-space ccoling to the vital power distribution rooms containing l

emergency battery chargers and inverters that depend on the inoperable emergency chilled water system for space cooling, and

' 2.

dithin 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months establish OPERABILITY of the safe shutdown j

systems which do not depend on the inoperable emergency chilled vater system (one train each of boration and auxiliary feedwater per Sections 3/4.1.2.2 and 3/4.7.1.2, respectively, and one bank of pressurizer heaters per Section 3/4.4.3) and 3.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months establish OPERABILITY of all required systems, subsystems, trains, components and devices that depend on the remaining OPERABLE emergency chilled water system for space cooling.

If these conditions are not satisfied within the specified time, 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 SHilTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

1 SURVEILLANCE REQUIREMENTS l

4.7.10 Each of the above required emergency chilled water systems shall be demonstrated OPERABLE:

i a.

At least once per 31 days by verifying that each manual valve servicing safety-related equipment that is not locked, sealed, or otherwise secured in position, is in its correct position and.

m SAN DNOFRE-UNIT ?

3/4 7-36 AMENDMENT NO. 28 l

REISSUED '8/26/89 1

EMERGENCY CHILLED WATER SYSTEM SURVEILLANCE RE0VIREMENTS (Continued) b.

At least once per refueling interval by verifying that:

each i

I power-operated or automatic valve servicing safety-related equipment actuates to its correct position and each chilled water pump starts automatically on a TGIS, CRIS, SIAS and, with irradiated fuel in the storage pool, FHIS.

SAN ONOFRE-UNIT 2 3/4 7-37 AMENDMENT N0. 75

-- L

7_

F M. ' '.

REISSLED 3/i5/33 ELECTRICAL POWER SYSTEM SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits between the offsite transmission network and the onsite Class IE distribution system shall be:

Determined OPdRABLE at least once per 7 days by verifying correct a.

breaker alignments and indicated power availability.

If tie breakers 3A0416 or 3A0603 are used to provide a source of-l power, the following busses are required.

for 3A0416 for 3A0603 3A04-W 3B04 3B06

-3D1 3D2 b.

. Demonstrated OPERABLE at least ont:e per refueling interval during shutdown by transferring (manually and automatically) unit power from the normal offsite power source to the alternate offsite power source.

The provisions or Technical Specification 4.0.2 are not applicable.

4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE:

a.

In accordance with the frequency specified in Tabie.4.8-1 on a STAGGERED TEST BASIS by:

1.

Verifying the fuel level in the day fuel tank, 2.

Verifying the fuel level in the fuel storage tank,'

3.

Verifying the fuel transfer pump can be started and transfers fuel from the storage system to the day tank, 4.

Verifying the diesel generator starts from ambient conditions and accelerates to at least 900 rpm.* The generator voltage and frequency shall be 4360 1 436 volts and 60 t i s Sz after reaching 900. rpm.

The diesel generator shall be st:u ted for this test by using one of the following signals:

A diesel generator start (in less than 10 seconds) from. ambient conditions shall be performed at least once per 184 days.. All other engine starts for the purpose of this surveillance testing may be preceded by an engine prelube period and/or other warmup procedures recommended by the manufacturer so the mechanical stress and wear on the diesel engine i"s minitized.

SAN ONOFRE - UNIT 2 3/4 8-2 AMENDMENT NO. 75 e

[..' *-

L. *

[

REISSUED 3/25/89

. ELECTRICAL P0kEP SYSTEM SURVEILLANCE REQUIREMENTS (Continued) a)

Marval b)

Simulated loss of offsite power by itself c)

Simulated loss of offsite power in conjunction with an ESF actuation test signal 5.

Verifying the generator is synchronized, loaded to greater than or equal to 4700 kw in less than or equal to 77 seconds *, and operates Oth a load greater thai or equal to 4700 kW for at ieast an aditional 60 minutes, ant' 6.

Verifying the diesel generator is aligned to provide standby power to the associated emergency busses, b.

At least once per 3 days and after each operation of the diesel where the period of operation was greater than or equal to I hour by checking for and removing accumulated water from the day tank.

c.1. At least once per 92 days and from new fuel oil prior to addition to the storage tanks by verifying that a sample obtained in accordance with ASTM-D4057-81 has a water and sediment content of less than or equal to.05 volume percent and a kinematic viscosity @ 40'C of greater than or equal to 1.9 but less than or equal to 4.1 when tested in accordance with ASTM-0975-81.

2.

At least once every 92 days by obtaining a sample of fuel oil in accordance with ASTM-D4057-81 and verifying that particulate contamination is less than 10mg/ liter when checked in accordance with ASTM-D2276-83, Method A.

d.

At least once per refueling interval ** (The provisions of Technical Specification 4.0.2 are not applicable) by:

1.

Subjecting the diesel to an inspection in ac;ordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service.

2.

Verifying the generator capability to reject a load of greater than or equal to 655.7 kW while maintaining voltage at 4360 1 436 volts and frequency at 60 1 5.0 Hz.

3.

Verifying the generator capability to reject a load of 4700 kW without tripping.

The generator voltage shall not exceed 5450 volts during and following the load rejection.

"All engine starts for the purpose of this surveillance testing may be preceeded by an engine prelube period and/or other warmup procedures recommended by the manufacturer so that mechanical stress and wear on the diesel engine is minimized.

- For cycle 4 only, this surveillance interval may exceed the 24 month refueling interval but may not exceed 25 months.

SAN ONOFRE - UNIT 2 3/4 8-3 AMENDMENT NO. 75 I

l 1

l ELECTE::AL PDdER Sr5 TEM SUCVE!LLAN:E REDUISEWENTS (Continued) 4 Simulating a loss of offsite power by itself, and:

a)

Verifying de-energization of the emergency busses and load shedding from the emergency busses.

b)

Verifying the diesel starts on the auto-start signal, energi2es the emergency busses with permanently connected loads within 10 seconds and operates for greater than or equal to 5 minutes while its generator is loaded with the permanently connected loads. After energization, the steady state voltage and frequency of the emergency busses shall be maintained at 4360 2 436 volts and 60 2 1.2 Hz during this test.

5.

Verifying that on an ESF test signal, without loss of offsite power, the diesel generator starts on the auto-start signal ano o;erates on standby for greater than or equal to 5 minutes.

The steady state generator voltage and frequency shall be 4360 2 436 volts and 60 2 1.2 Hz within 10 seconds after the auto-* tart signal; the generator voltage and frequency shall be maintained within these limits during this test.

6.

De'eted.

7.

Simulating a less of offsite power in conjunction with an E5F test signal, and a)

Verifying de-energization of the emergency busses and load shedding from the emergency busses, b)

Verifying the diesel starts on the auto-start signal, energizes the emergency busses with permanently connected leads within 10 seconds, energizes the auto connected emergency (accident) loads through the load sequence and nperates for greater than or equal to 5 minutes while its generator is loaded with the emergency leads. After loading, the steady state voltage and frequency of the emergency busses shall be saintained et 4360 2 436 volts and 60 + 1.2/-0.3 Hz during this test.

c)

Verifying that all automatic diesel generator trips, except engine overspeed, generator differential and low-low lube oil pressure, are automatically bypassed.

SAN ONOFRE - UNIT 2 3/4 8-4 AMENDMENT NO. 59

e ELECTRICAL POWER SYSTEMS ONSITE POWER DISTRIBUTION SYSTEMS SHUTDOWN LIMITING' CONDITION FOR OPERATION 3.8.3.2 As a minimum, the following electrical busses shall be energized in the specified manner:

a.

-One~ division of A.C. Emergency Buses consisting of one 4160-volt and one 4BO-volt A.C. Emergency Bus.

120. volt A.C. Vital Busses energized from their associated

. b.

2 inverters connected to their respective D.C. Busses.

125 volt D.C. Busses energized from their associated battery c.

2 banks.

APPLICABILITY: MODES 5 and 6 ACTION:

With any of the above required electrical betses not energized in the required manner, immediately suspend all operations involving CORE ALTERATIONS, positive reactivity changes, or movement of irradiated fuel, initiate corrective action to energize the required electrical busses in the specified manner as soon as possible.

SURVEILLANCE REQUIREMENTS 4.8.3.2 The specified busses shall be determined energized in the required manner at least once per 7 days by verifying correct breaker alignment and indicated voltage on the busses.

e SAN ONOFRE-UNIT 2 3/4 8-15.

I

~.

-REISSUED 8/25/89 ELECTRICAL POWER SYSTEMS 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTIVE DEVICES CONTAINMENT = PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES LIMITING CONDITION FOR OPRATION 3.8.4.1 All containment penetration conductor overcurrent protective devices shown in Table 3.8-1 shall be OPERABLE.

i/ PLACABILITY:

MODES 1, 2, 3 and 4.

ACTION:

With one or more of the above required containment penetration conductor overcurrent protective device (s) inoperable:

Restore the protective device (s) to OPERABLE status or de-energize a.

the circuits (s) by tripping the associated backup circuit breaker or racking out or removing the inoperable circuit breaker within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the affected system or component inoperable, and verify the backup circuit breaker to be tripped or the inoperable circuit breaker racked out, or removed, at least once per 7 days thereafter; the provisions of Specification 3.0.4 are not applicable to overcurrent devices in circuits which have their backup circuit breakers tri.. ped, their inoperable circuit breakers racked out, or removed, 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 and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.8.4.1 All containment penetration conductor overcurrent protective devices shown in Table 3.9-1 shall be demonstrated OPERABLE:

a.'

At least once per refueling interval:

l 1.

By verifying that the medium voltage (4-15 KV) circuit breakers are OPERABLE by selecting, on a rotating basis, at least 10% of the circuit breakers of each voltage level, and performing the following:

(a) A CHANNEL CALIBRATION of the associated protective relays, and (b) An integrated system functival test which includes simulated automatic actuation of the system and verifying that each relay and associated circuit breakers and control circuits function as designed.

SAN ONOFRE-UNIT 2 3/4 8-16 AMENDMENT NO. 75 I

REISSUED 8/25/89 ll J

QECTRICALPOWER-SYSTEMS MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS LIMITING CONDITION FOR OPERATION 3.8.4.2 The thermal overload protection shall be bypassed by a bypass device integral with tne motor starter of each valve listed in' Table 3.8.2.

l APPLICABILITY: Whenever the motor operated valve is required to be OPERABLE.

ACTION:

With the thermal overload protection not bypassed by the integral bypass device, bypass the thermal overload protection within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or declare the affected valve (s) inoperable and apply the appropriate ACTION Statement (s) for the affected valve (s).

-SURVEILLANCE REQUIREMENTS 4.8,4.2 The above required thermal overload protection shall be verified to be bypassed by integral bypass devices:

a.

At least once per refueling interval, l

b.

Following maintenance on the valve motor starter, and c.

Following any periodic testing during which the thermal overload device was temporarily placed in force.

SAN ONOFRE-UNIT 2 3/4 8-31 AMENDMENT NO. 75 L

1 1

TABLE 3.8-2 j

L MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICES Permanently Bypassed VALVE NUMBER FUNCTION

~

HV-9339 Shutdown cooling flow from reactor coolant loop 2 HV-9340 51 tank T008 to reactor coolant loop 1A HV-9370 SI tank T010 to reactor coolant loop 2B HV-9347 SI pump minimum recirculation HV-9322 LPSI Header to reactor coolant loop 1A HV-9331 LPSI Header to reactor coolant loop 2B HV-9348 SI pump minimum recirculation HV-9323 HPSI Header #2 to reactor coolant loop 1A HV-9332 HPSI Header #2 to reactor coolant loop 2B HV-9217 RCP bleed off to volume control tank - cent. isol.

HV-9326 HPSI Header #2 to reactor coolant loop 1B HV-9329 HPSI Header #2 to reactor coolant loop 2A-HV-7258 Waste gas surge tank header containment isolation i

HV-0508 Reactor coolant hot leg #1 sample containment isolation HV-0517 Reactor coolant hot leg #2 sample containment isolation HV-9368 Shutdown HX E003 to containment spray Header #2 HV-0510 Pressurizer vapor sample containment isolation HV-0512 Pressurizer surge line liquid sample containment isolation i

HV-9950 Containment purge outlet to exhaust unit A060 - cont. isol.

HV-9917 Hydrogen purge exhaust unit A082 inlet - containment isol.

HV-9946 Hydrogen purge supply unit A080 dissharge - containment isol.

SAN ONOFRE-UNIT 2 3/4 6-32 Amendment No. 4 I

I

]

REISSUED 5/25/53

![ ',;... %*'c.

UNITED STATES

-\\

',j NUCLEAR REGULATORY COMMISSION f

N' /s/

WASHINGTON, D. C. 20555 s,,,,,.

l SOUTHERN CALIFORNIA EDISON COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RIVERSIDE, CALIFORNIA THE CITY OF AMAHEIM, CALIFORNIA DOCKET NO.60-362 S/J; Cf;0FRE huCLEAR GENERATING STATION, UNIT NO. 3 APENDPEtiT TO FACILITY OPERATING LICENSJ Amendment No. 63 License No. NPF-15 1.

The f.uclear Regulatory Cornission (the Connission) has found that:

A.

The applications for amendment to the license for San Onofre Nuclear Generating Station, Unit 3 (the facility) filed by Southern Califernia Edison Company (SCE) on behalf of itself and San Diego Gas and Electric Company, the City of Riverside, California and the City of Anaheim, California (licensees) dated April 26, October 11, October 24, November 7, and December 16, 1988; and January 16, January 20, and March 28, 1989 comply with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Cosmission's regulations set forth in 10 CFR Chapter I; B.

The facility will operate in confomity with the applications, the provisions of the Act, and the regulations of the Cosmission; 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 amendsent will not be inimical to the cosmon defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Cornission's regulations and e11 applicable requirements have been satisfied.

4 I

, 2.

A:ccrdincly, the license is amended by changes to the Technical Spect.

ficaticr.s as indicateo in the attachment to this license amendment, and paragraph 2.C(2) of Facility Operating License No. NPF-15 is hereby r

amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A, and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No.63, are hereby incorporated in the license. SCE shall operate the facility in accordance with the Technical Specifications and the Environmental Frotection Flan.

3.

This literse amendment is effective as of the date of its issuance and ust be fully implemented no later than 30 days from the date of issuance.

FOR THE NUCLEAR REGULATORY CDPNISSION

/

George W. Kni ton, Director Project Directorate Y Divistor, of Reactor Projects - III, IV, Y and Special Projects

Attachment:

Changes to the Technical Specifications Date of Issuance: July 28,129 O

e G

.. I

REISSUED S/25/53 ATTACHMENT TO LICENSE AMENDMENT NO. 63 FACILITY OPERATING LICENSE NO. NPF-15 DOCKET NO. 50-362 Revise Appendix A Technical Specifications by removing the pages identified below and inserting the enclosed pages. The revised pages are identified by amendment number and contain marginal lines indicating the area of change.

Also enclosed are the following overleaf pages to the amended pages.

I AMENDMENT PAGE OVERLEAF PAGE 3/4 3-1 3/4 3-2 3/4 3-13 3/4 3-14 3/4 3-44 3/4 3-43 3/4 3-76 3/4 3-75 3/4 6-29 3/4 7-5 3/4 7-6 3/4 7-12 3/4 7-11 3/4 7-13 3/4 7-14 3/4 7-28 3/4 7-27 3/4 7-36 3/4 7-37 3/4 8-2 3/4 8-3 3/4 8-4 3/4 8-16 3/4 8-15 3/4 8-31 3/4 8-32 6

m o

4 I

.;~

REISSUED 8/25/89 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTIVE INSTRUMENTATION LIMITING COND'ITION FOR OPERATION 3.3.1 As a minimum, the reactor protective instrumentation channels.and bypasses of Table 3.3-1 shall be OPERABLE with RESPONSE TIMES as shown in Table 3.3-2.

APPLICABILITY: As shown in Table 3.3-1.

ACTION:

As shown in Table 3.3-1.

1 SURVEILLANCE RE0VIREMENTS 4.3.1.1 Each reactor protective instrumentation channel shal1~be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations for the MODES and at the frequencies showr.

in Table 4.3-1.

4.3.1.2 The logic for the bypasses shall be demonstrated OPERABLE prior tc each-reactor startup unless performed during the preceding 92 days. The total bypass function shall be demonstrated OPERABLE at_least once per refueling interval for each channel affected by bypass operation.

The provisions of Technical Specification 4.0.2 are not applicable.

4.3.1.3 The REACTOR TRIP SYSTEM RESPONSE TIME of each reactor trip function shall be demonstrated to be within its limit at least once per 18 months.

'Each test shall include at least one channel per function such that all channels are tested at least once every N times 18 months where N is the total number of redundant channels in a spec'ific reactor trip function as shown in the " Total No. of Channels" column of Table 3.3-1.

4.3.1.4 The isolation characteristics of each CEA isolation amplifier and each optical isolator for CEA' Calculator to Core Protection Calculator data transfer shall be verified at least once per 18 months during the shutdown per

- the following tests:

a.

For the CEA position isolation amplifiers:

1.

With 120 volts AC (60 Hz) applied for at _least 30 seconds across the output, the reading on the input does not exceed 0.015 volts DC.

SAN ONOFRE - UNIT 3 3/4 3-1 AMENDMENT NO.63 I

!~

INSTRUMENTATION SURVEILLANCE REQUIREMENTS (Continued) 2.

With 120 volts AC (60 Hz) applied for at least 3'O seconds across the input, the reading on the outp,ut does not exceed 8 volts DC.

b.

For the optical isolators: Verify that the input to output insulation resistance is greater than 10 megohms when tested using'a megohmmeter on the 500 volt DC range.

~

4.3.1.5 The Core Protection Calculator System shall be determined OPERABLE at' least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifyir.g that less than three auto restarts have occurred on each calculator during the past 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.3.1.6 The Core Protection Calculator System shall be subjected to a CHANNEL FUNCTIONAL TEST to verify OPERABILITY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of receipt of a High CPC Cabinet Temperature alarm.

l 1

SAN ONOFRE-UNIT 3 3/4 3-2 l

REISSUED 8/25/89 INSTRUMENTATION 1

.3/4.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION' 3.3.2 The Engineered Safety Features Actuation System (ESFAS) instrumentation channels and bypasses shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-4 and with RESPONSE-TIMES as shown in Table 3.3-5.*

APPLICABILITY: As shcwn'in Table 3.3-3.

ACTION:

a.

With an ESFAS instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3-4, declare the channel inoperatle and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint value.

b.

With an ESFAS instrumentation channel inoperable, take the ACTION shown in Table 3.3-3.

SURVEILLANCE REQUIREMEN15 4.3.2.1 Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations for the MODES and at the frequencies shown in Table 4.3-2.

4.3.2.2 The logic for the bypasses shall be demonstrated OPERABLE.during the at power CHANNEL FUNCTIONAL TEST of channels affected by, bypass operation.

~

The total bypass function shall be demonstrated OPERABLE at least once per refueling interval for each channel affected by bypass operation.

The provisions of Technical Specification 4.0.2 are not applicable.

I l

4.3.2.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months.

Each test shall include at least one channel per function such that all channels are tested at least once every N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the

" Total No. of Channels" Column of Table 3.3-3.

Continuous monitoring and sampling of the containment purge exhaust directly from the purge stack shall be provided for the low and high volume (8-inch and 42-inch) containment purge prior to startup following the first refueling outage. Containment airborne monitor 3RT-7804-1 or 3RT-7807-2 and associated sampling media shall p2rform these functions prior to initial criticality.

From initial criticality to the startup following.the fJrst refueling outage containment airborne monitor SRT-7804-1 and assrefated sampling media shall perform the above required functions.

SAN ONOFRE - UNIT 3 3/4 3-13 AMENDMENT NO.63 l

N 0

0 0

O 1

1 1

I T

C A

8 9

9 9

8 9

9 8

8 9

9 E

4

)

4 4

L a

BS

(

AE 3

3 3

CD I O N

LN 2

2 2

O P

I P

T A

1 1

1 A

T N

EN 2

U 2

2 2

R f

f f

f T

SE o

o o

o S

MLL N

UEB s

s s

s NNA t

t t

t I

I NR e

e e

e N

NAE s

s s

s HP E

I T

MCO 2

3 3

2 2

3 3

2 2

3 3

S YS N

3 O

2 2

I 3

T S

f f

A LP o

o o

o 3

U EI T

NR t

t t

t E

C NT e

e

)

e e

L A

A s

s b

s s

B HO

(

A S

CT 1

2 2

2 1

2 2

1 T

E I

2 2

RU T

A 2

2 2

2 E

F

.S f

f f

f OL o

o o

o Y

NE T

N s

s s

s E

LN t

t t

t F

AA e

e e

e A

TH s

s s

s S

OC T

2 4

4 4

2 4

4 2

2 4

4 O

F E

O R

)

E S

E A

N

)

I I

s e e

) s e C

e G

) n r r

n Sn r n

(

r n

N So u u

o Ao u o

u o

E At s s

i St s i

Np p

s i

It s

s t

Ct s t

Oi i

s t

Su e e

a

( u e a

I r r

e a

(B r

r u

B r u

TT T) r u

P P

t Y

Ph t A(

( c P t

Mp c

Ap g c L

(

c Oi t r

A Ri ti A OS S

t A

I r n e

P r nH SA) A) n TT e z

c ST e c

II s I s e c

C( m i

i

(

m-i Cn Sn m i

E n

r t c T

n t c T

o o n tc T

Jl ih u

ai Nl ih ai Nlt lt ih ai I

Na ag sw mg E a ag mg Eat at ag mg N

I u ti so oo Mu ti oo Nuu uu ti oo U

n nH eL tL Nn nH tl NnB nB nH tL Ya o r

u I a o u

I a a

o u

L TM C P

A AM C A

AM M

C A

A E

T T

N F

N N

O A

O.

O I

Sa b c

d Ca b c

Ca b

c d

T I

C N

U F

1 2

3 vE o5 ; E 4 w R* 3*

s TABLE 3.3-7 SEISMIC MONITORING INSTRUMENTATION Minimum

-Measurement Instrument Instruments & Sensor Locations

Range Operable 1.

Triaxial Time-History Strong Motion Accelerometers a.

Steam Generator Base Support

-2 to +2g I

b.

Pressurizer Base Support

-2 to +2g I

c.

Reactor Coolant Pump

-2 to +2g 1

d.

Containment Base in Tendon Gallery

-2 to +2g I

e.

Containment Operating Level

-2 to +2g I

f.

Unit #1 Free Field

-1 to'+1g 1

g.

Centrol Building Basement

-2 to +2g I

h.

Control Building Roof

-2 to +2g 1

i.

Safety Equipment Building Base Slab

-2 to +2g 1

j.

Safety Equipment Building Piping Support

-2 to +2g I

k.

Radwaste Building Equipment Support

-2 to +2g 1

2.

Triaxial Peak Reading Accelerographs a.

Control Building Control Room

-2 to +2g 1

b.

Control Building Base

-2 to +2g I

c.

Top of Containment Structure

-5 to +5g 1

d.

Reactor Coolant Piping

-2 to +2g 1

3.

Seismic Triggers a.

Containment Base in Tendon Gallery

+0.005 to +0.05g 1

b.

Containment Operating Level

+0.005 to +0.05g 1

4.

Seismic Switches a.

Steam Generator Base Support Set pt. 0.45 Horz/0.30 Vert.

1**

b.

Containment Base in Tendon Gallery Set pt. 0.40 Horz/0.50 Vert.

1**

5.

Seismic Alarm Annunciator (4a & 4b are sensors) a.

Control Room Panel L-167 6.

Peak Shock Recorder a.

Containment Base in Tendon Gallery 2 to 25.4 Hz 1**

1.6 to 90g 7.

Peak Shock Annunciator 2 to 25.4 Hz 1

1.6 to 90g a.

Control Room Panel L-167 AAll seismic instrumentation is located in San Onofre Unit 2 with the exception of item 1.f. which is located in San Onofre Unit IT' enWith control room indication SAN ONOFRE-UNIT 3 3/4 3-43 ll

REISSUED 8/25/89 l

t TABLE 4.3-4 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS j

CHANNEL CHANNEL FUNCTIONAL FUNCTIONA.

g INSTRUMENTS AND SENSOP LOCATIONS CHECK CALIBRATION TEST 1.

Triaxial Time-History Strong Motion Accelerometers a.

Steam Generator Base Support M*

(1)

SA l

b.

Pressurizer Base Support M*

(1)

SA c.

Reactor Coolant Pump M*

(1)

SA d.

Containment Base in Tendon Gallery M*

(1)

SA e.

Containment Operating Level M*

(1)

SA-f.

Control Building Basement M*

(1)

SA g.

Control Building Roof' M*

(1)

SA h.

Safety Equipment Building Base M*

(1)

SA i.

Safety Equipment Building Piping Support M*

(1)

SA j.

Radwaste Buildino Fquipment Support M*

(1)

SA 2.

Triaxial Peak Recording Accelerographs a.

Control Building-Control Room N/A (1)

N/A b.

Control Building Base N/A (1)

N/A c.

Top of Containment-Structure N/A (1)

N/A d.

Reactor Coolant Piping N/A (1)

N/A 3.

Seismic Triggers a.

Containment Base in Tendon Gallery M

(1)

SA l

b.

Containment Operating Level M

(1)

S/U***

4.

Seismic Switches a.

Steam Generator Base Support M

(1)**

.SA**

b.

Containment Base in Tendon Gallery M

(1)**

SA**

5.

Seismic Alarm Annunciators (4a & 4b are sensors) a.

Control Room Panel L-167 M

(1)

SA 6.

Peak Shock Recorder a.

Containment Base in Tendon Gallery N/A (1)**

N/A 7.

Peak Shock Annunciator a.

Control Room Panel L-167 N/A (1)**

N/A All seismic instrumentation is located in San Onofre Unit 2.

Except seismic trigger With Control Room indication

- - Need not be performed more frequently than once per 6 months.

(1) Once per refueling interval. The provisions of Technical Specification 4.0.2 are not applicable.

SAN ONOFRE - UNIT 3 3/4 3-44 AMENDMENT NO.63 3

x

..-_-1---.____-

-_._---_a--_.t.-_---a-----___-__________-_'-_---.-

La:*

e -

f TABLE 4.3-9 (Continued)

TABLE NOTATION

At all times.

- During waste gas holdup system optration (treatment for primary system offgases).

"** MODES 1-4 with any main steam isolation valve and/or any main steam isolating valbe bypass valve not fully closed.

(1) The CHANNEL CONCTIONAL TEST shall also demonstrate that automatic any of the following conditions exists:gom alarm annunciation occurs if isolation of this pathway and control r 1.

Instrument indicates measured levels above the alarm / trip setpoint.

2.

Circuit failure.

3.

Instrument indicates a downscale failure.

(2) The CHANNEL FUNCTIONAL TEST shall also demonstrate that control roop:

alarm annunciation occurs if any of the following conditions exists 1.

Instrument indicates measured levels above.the alarm setpoint.

2.

Circuit failure.

3.

Instrument indicates a downscale failure.

l (3) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the Naticnal Bureau of Standards or using' standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards shall

~

permit calibrating the system over its intended range of energy and measurement range.

For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

(4)~ The' CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:

.1.

One volume percent hydrogen, balance nitrogen, and 2.

Four volume percent hydrogen, balance nitrogen.

(5) The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:

1.

One volume percent oxygen, balance nitrogen, and 2.

Four volume percent oxygen, balance nitrogen.

(6) Prior to each release and at least once per month.

(7) Prior to completion of DCP53N, these surveillance ' requirements are to be performed on the instruments indicated by Table 3.3-13.

"If the instrument controls are not set in the operate mode, procedures shall call'for declaring the channel inoperable.

SAN ONOFRE-UNIT 3 3/4 3-75 AMENDMENT NO. 20 I

REISSUED 8/25/89 t

' INSTRUMENTATION LOOSE-PART DETECTION' INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.10 The loose part detection system shall be OPERABLE.

APPLICABILITY: -MODES 1 and 2.

ACTION:

With one or moreiloose.part detection system channels inoperable for-a.

more than 30 days, prepare and submit a Special Report to the Commission pursuant to Specification _6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status, b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.'10 Each channel of the loose part detection system shall be demonstrated OPERABLE by performance of a:

a.

CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , b.

CHANNEL FUNCTIONAL TEST at least once per 31 days, and c.

CHANNEL CALIBRATION at least once per refueling interval.

. SAN ONOFRE - UNIT 3 3/4 3-76 AMENDMENT NO.63

- - - - - - - - - - - - - - - - - - - ' - - - ^ ^ ^ - - - - -

~ ^--

REISSUED 8/25/89 s

CONTAINMENT SYSTEMS CONTAINMENT DOME AIR CIRCULATORS LIMITING CONDITION FOR OPERATION 3.6.4.3 Two independent dome air circulator trains shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTION:

With one dome air circulator train inoperabl.>. restore the inoperable train to OPERABLE status within 30 days or be in at it'st HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.6.4.3 Each dome air circulator train shall be demonstrated OPERABLE:

a.

At least once per refueling interval f y starting each train on a 1

CCAS signal and verifying that the system operates for at least 15 minutes.

b.

At least once per refueling interval by verifying a system flow rate of at least 37,000 cfm.

SAN ONOFRE-UNIT 3 3/4 6-29 AMENDMENT N0. 63

_I

REISSUED 8/25/89 4

g i

1 PLANT' SYSTEMS.

l q

SURVEILLANCE REQUIREMENTS (Continued)

E

.4.

Verifying-that the AFW piping is full of water by venting the accessible discharge piping.high points.

~

b.

At.least once-per. refueling interval during shutdown by:

1.

Verifying that each automatic valve in the flow path actuates =

to its correct position upon receipt of an EFAS test signal.

2.

Verifying that each pump starts automatically upon receipt of l

an EFAS test signal.

4.7.1.2.2 The auxiliary feedwater system shall be demonstrated OPERABLE prior to entering. MODE 2 following each COLD SHUTDOWN by. performing a ' flow test to verify the normal. flow path from the primary AFW supply tank (condensate stor-age tank T-121) through each. auxiliary.feedwater' pump to-its associated steam generator.

I M

i SAN ONOFRE-UNIT 3 3/4 7-5 AMENDMENT NO.63 I

~

PLANT SYSTEM.5 CONDENSATE STORACE TANKS LIMITING CONDITION FOR OPERATION-3.7.1.3 The condensate storage tanks (CSTs) shall be OPERABLE with a contained volume of at lea'st 144,000 gallons" in T-121 and 280,000,ga11ons in L

T-120.

APPLICABILITY:

MODES 1, 2 and 3.

ACTION:

With the. condensate storage tanks inoperable, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either restore the CSTs to OPERABLE status or be in at least HOT STANDBY within the next 6 nours and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE RE0VIREMENTS 4.7.1.3 The condensate storage tanks shall be demonstrated OPERABLE-at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying the contained water volume is within its limits.

l

.Prior to first achieving 100% power, the minimum volume required to be contained in T-121 is that shown on Figure 3.7-1 corresponding to the maximum power level achieved to date.

SAN ONOFRE-UNIT 3 3/4 7-6 L

3 PLANT SYSTEMS-3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION LIMITING CONDITION FOR OPERATION 3.7.2 The temperatures of both the primary and secondary coolants in the steam generators shall be greater than 70*F when the pressure of either cool-ant 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 detertaine 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 REQUIREMENTS 4.7.2 The pressure in each side of the steam generators shall be determined to be less than 700 psig at least once per hour when the temperature of either the primary or secondary coolant is less than 70*F.

SAN DNOFRE-UNIT 3 3/4 7-11 L_

y q,A.

.. y

,t

'RE!SSUED'8/25/89 D.

n

' PLANT SYSTEMS-3/4.7.3 COMPONENT COOLING WATER SYSTEM j

LIMITING'CONDIM ON FOR OPERATION p

3.7.3 ' At least two independent component cooling water loeps shall be

[

l OPERABLE.

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

1' ACTIOp With only one component cooling water loop OPERABLE, restore at least two loops 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 j

'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' hours.

j SURVEILLANCE REQUIREMENTS

'i

.I 4-7.3' At least two component cooling water loops shall be demonstrated

.0PERABLE:

f

-a

,c At least.once per 31 days by verifying that each valve'(manual, po.sr operated or automatic) servicing safety related equipment that is not locked, sealed, or otherwise' secured in' position, is in its u

j

' correct position.

'n b.

At'. least once per refueling interval during shutdown by verifying '

that each automatic valve servicing safety related equipment acteates to its correct position and'each component cooling water pump starts automatically on an SIAS test signal.

n

.:r,

'{.

'h SAN ONC' UNIT 3 3/4 7-12 AMENDMENT NO. 63

(<

1

f,.i

?

a.cq 71h',

t PLANT SYSTEMS an 3/4.7.4 SALT WATER COOLING SYSTEM LIMITING CONDITION FOR OPERATION pI 3.7.4 At least two independent salt water cooling loops shall'be OPERABLE.

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

ACTION:

3 With only one salt water cooling loop OPERABLE, restore at least two loops to

.0PERABLE 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 COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

e q-l:

(

SURVEILLANCE _E REQUIREMENTS

.c 4.7.4-(At least two salt water cooling' loops shall' be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each-valve (manual,

'e

. power operated or automatic) servicing safety related equipment tnat is not locked, sealed or ctherwise secured in position, is in its '

-4 correct position.

1 *.

- b '.'

At.least once per refueling interval during shutdown, by verifyin'g that each automatic valve servicing safety-related equipment actuates to its

' correct position and each salt water cooling pump starts automatically

.. o on an SIAS test signal.

l l-f.

SAN ONOFRE-UNIT 3 3/4 7-13 AMENDNENT 'NO. 63 I

1 l,

PLINT SYSTEMS 3/c.7.5 CONTROL ROOM EMERGENCY AIR CLEANUP SYSTEM" LIMITING CONDITION FOR OPERATION j

3.7.5 Two independent control room emergency air cleanup systems shall be c

l OPERABLE.

APPLICABILITY: ALL MODES

h n y

ACTION:

Unit 2 or 3 in MODES 1, 2, 3 or 4:

With one control room emergency air cleanup system 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 SHU]DOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Units 2 and 3 in MODES 5 or 6:

With one control room emergency air cleanup system inoperable, a.

' restore the inoperable system to OPERABLE status within 7 days or initiate and maintain operation of the remaining. OPERABLE control room errergency air cleanup system in the recirculation mode.

b.

With.both control room emergency air cleanup systems inoperabic, or with the.0PERABLE control room emergency air cleanup system required to be in the recirculation mode by ACTION' a powered by an DPERABLE emergency power sour (ce).. not capable of being

, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.

The provisions of Specification 3.0.3 are not applicable in MODE G.

c.

_ SURVEILLANCE REQUIREMENTS 4.7.5 Each control room emergency air cleanup system shall be demonstrated

, OPERABLE:

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the control room air a.

temperature is less than or equal to 110*F.

b.

At least once per 31 days on a STAGGERED TEST SASIS by initating, I

f rom the control room, flow through the HEPA filters and charcoal

{

adsorbers and verifying that the system operates for at least 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months with the heaters on.

At least once per 18 months or (1) after any structural maintenance c.

on the HEPA filter or charcoal adsorber, housings, or (2) following painting, fire or\\ chemical release in any ventilation zone communicating with the system by:

(

1.

Verifying that with the system operating at a flow rate of l

35485 cfm + 10% for the air conditioning unit, and 2050 1 150 cfc.

for the velitilation unit and recirculating through the respective HEPA filters and charcoal adsorbers, leakage through the system diverting valves is less than or equal to 1% air conditioning unit and 1% ventilation unit when the system is tested by admitting cold DOP at the respective intake.

l A

Shared system with San Onofre - Unit 2.

1 SAN ONOFRE-UNIT 3 3/4 7-14 AftCNDMENT NO. 3 l1l

r.

6 PLANT SYSTEMS 3/4.7.8 FIRE SUP,PRESSION SYSTEMS FIRE SUPPRESSION WATER SYSTEM LIMITING CONDITION FOR OPERATION 1

3.7.8.1 The fire suppression water system shall be OPERABLE with:

a,

- Two electric motor-driven fire pumps, each with a capacity of 1500 gpm and one diesel-criven fire pump with a capacity of 2500 gpm, with their discharge aligned to the fire suppression

header, b.

Two separate water supplies, each with a minimum contained volume of 300,000 gallons ~, and c.

An OPERABLE flow path capable of taking suction from each water supply and transferring the water through distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valves, the first valve upstream of the water flow alarm device on each spray and/or sprinkler or fire hose station required to be OPERABLE per Specifications 3.7.8.2 and 3.7.8.3.

APPLICABILITY: At all times.

ACTION:

a.

With one required electric motor-driven / diesel-driven pump and/or one water supply inoperable, restore the inoperable equipment to OPERABLE statt. within 7 days or provide an alternate backup pump or supply.

~

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

b.

With the fire suppression water system otherwise inoperable, establish a backup fire suppression water system within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS 4.7.8.1.1 The fire suppression water system shall be demonstrated OPERABLE:

a.

At least once per 7 days by verit'ying the contained water supply vol ume.

b.

At least once per 31 days on a STAGGERED TEST BASIS by starting each electric motor-driven pump and operating it for at least 15 minutes on recirculation flow.

c.

At least once per 31 days by verifying that each valve (manual, power-operated or automatic) in the f40w path is in its correct position.

i SAN ONOFRE-UNIT 3 3/4 7-27 l

i REISSUED '8/25/39

.i-i PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continueo)'

d.

At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.

e At least once per 18 months by performing a system functional test which includes simulated automatic actuation of the system through-out its operating sequence, and:

1.

Verifying performance of the fire pumps as follows:

a.

Diesel engine-driven pump develops at least 2500 gpm at a systern head of 283 feet.

'i,'

b.

Electric motor-driven pumps each develop at least 1500 gpm at a system head of 289 ft.

2.

Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full travel," and I

3.

Verifying that each fire suppression pump starts (sequentially) to maintain the fire suppression water system pressure greater than or equal to 95 psig.

f.

At least once per 3 years by performance of a system flush g.

At-least once per 3 years by performing a flow test of the system in accordance with Chapter 5, Section 11 of the Fire Protection Handbook, 14th Edition, published by the National Fire Protection Association.

4.7.8.1.2 The fire pump diesel engine shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying:

1.

The diesel fuel oil day storage tank contains at least 225 gallons of fuel, and 2.

The diesel starts from ambient conditions and operates for at leest 30 minutes on recirculation flow.

b.

At least once per 92 days by verifying that a sample of diesel fuel from the fuel storage tank, obtained in accordance with ASTM-D270-1975, is within the acceptable limits specified in Table 1 of ASTM D975-1977 when checked for viscosity, water and sediment.

~

c.

At least once per 18 months during shutdown, by subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for the class of service.

i

" Refueling interval for those plant areas that are inaccessible during non-refueling operations.

SAN ONOFRE-UNIT 3 3/4 7-28 AMENDMEN1 NO. 63 1

.I

g

.g 1

PLANT SYSTEMS 3/t. 7.20 EMERGENCY CHILLED WATER SYSTEM

- LIMITING CONDITION FOR OPERATION l

3.7.10 Two independent emergency chilled water systems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

a.

With only one emergency chilled water system OPERABLE, 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 only one emergency chilled water system OPERABLE:

1.

Within 1 hout verify that the normal HVAC system is providing space cooling to the vital power distribution rooms containing emergency battery chargers and inverters that depend on the inoperable emergency chilled water system for space cooling, and i

Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months establish OPERABILITY of the safe shutdown systems which do not depends on the inoperable emergency chilled water system (one train each of boration and auxiliary feedwater per Sections 3/4.1.2.2 and 3/4.7.1.2, respectively, and one bank of pressurizer heaters per Section 3/4 4.3) and 3.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months establish OPERABILITY of all required systems, subsystems, trains, components and devices that depend on the remaining OPERABLE emergency chilled water system for space cooling.

If these r.onditions are not satisfied within the specified time, 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 ar,d in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.10 Each of the above required emergency chilled water systems shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each manesi valve servicing safety-related equipment that is not locked, sealed, or otherwise secured in position, is in its correct position and, AMENDMENT NO. 17 SAN ONOFRE-UNIT 3 3/4 7-37 L

REISSUED'8/25/89 EMERGENCY CHILLED WATER SYSTEM SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per refueling interval by verifying that:

each power-operated or automatic valve servicing safety-related equipment actuates to its correct position and each chilled water pump starts automatically on a TGIS, CRIS, SIAS and, with irradiated fuel in the storage pool, FHIS, J

=

SAN ON0FRE-UNIT 3 3/4 7-38 AMENDMENT NO.63

- = _ - _ _ _ _ _.

REISSUED 8/25/89 ELECTRICAL POWER SYSTEMS ACTION (Continued)

SURVEILLANCE RE0VIREMENTS 4.8.1.1.I' Each of the-above required independent circuits between the offsite transmission network and each Class 1E 4 kV Bus shall be:

a.

Determined OPERABLE at least once per 7 days by verifying correct breaker alignments and indicated power availability.

If tie breakers 2A0416 or 2A0603 are used to provide a source of power, the following busses are required.

for 2A0416 for 2A0603 2A04 W

2B04 2B06 2D1 202 b.

Demonstrated OPERABLE at least once per refueling interval during shutdown by transferring (manually and automatically) unit power from the normal offsite power source to the alternate offsite power source. The provisions of Technical Specification 4.0.2 are not applicable.

4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE:

a.

In accordance with the frequency specified in Table 4.8-1 on a STAGGERED TEST BASIS by:

l 1.

Verifying the fuel level in the day fuel tank, 2.

Verifying the fuel level in the fuel storage tank, 3.

Verifying the fuel transfer pump can be started and transfers fuel from the storage system to the day tank, 4.

Verifying the diesel' generator starts from ambient conditions and accelerates to at least 900 rpm." The generator voltage tv frequency shall be 4360 1 436 volts and 60 i 1.2 Hz after reahing 900 rrm. The diesel generator shall be started for this test by using the manual start signals:

1 a)

Manual b)

Simulated loss of offsite power by itself c) l3imulated loss of offsite power in conjunction with an ESF actuation test signal

A diesel generator start (in less than 10 seconds) from ambient conditions shall be perfcrmed at least once per 184 days. All other engine starts for the purpose of this surveillance testing may be preceded by an engine'prelube period and/or other warmup procedures recommended by. the manufacturer so that mechanical strass and wear on the diesel engine is minimized.

SAN ONOFRE-UNIT 3 3/4 8-2 AMENDMENT NO. 63 lIa

~l

REISSUED 8/25/89 ELECTRICAL-POWER SYSTEM SURVEILLANCE REQUIREMENTS (Continued) 5.

Verifying the generator is synchronized, loaded to greater than or equal to 4700 kW in less than or equal to 77 seconds *, and operates with a load greater than or equal to 4700 kW for at least an additional 60 minutes, and 6.

Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.

b.

At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months by checking for and removing accumulated water from the day tank.

c.1. At least once per 92 days and from new fuel prior to addition to the storage tanks by verifying that a sample obtained in accordance with ASTM-04057-81 has a water and sediment content of less than or equal to.05 volume percent and a kinematic viscosity @ 40 C of greater than or equal to 1.9 but less than or equal to 4.1 when tested in accordance with ASTM-D975-81.

'2. At least once every 92 days by obtaining a sample of fuel oil in accordance with ASTM-D4057-81 and verifying that particulate con-tamination is less than 10mg/ liter when checked in accordance with ASTM D2276-83, Method A.

d.

At least once per refueling interval (the provisions of Technical Specification 4.0.2 are not applicable) by:

1.

Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service.

2.

Verifying the generator capability to reject a load of greater than or equal to 655.7 kW while maintaining voltage at 4360 1 436 volts and frequency at 60 1 5.0 Hz.

3.

Verifying the generator capability to rsject a load of 4700 kW without tripping. The generator voltage shall not exceed gj450voltsduringandfollowingtheloadrejection.

l l

All engine starts for the purpose of this surveillance testing may be pre-ceded by an engine prelube period and/or other warmup procedures recommended by the manufacturer se that mechanical stress and wear-on the diesel engine is minimized.

i l

SAN ONOFRE-UNIT 3 3/4 8-3 AMENDMENT NO. 63 L

iL

ELECTRICAL POWER SYSTEMS SURVEILLAN_CE REQUIREMENTS (Continued) 4.

Simulating a loss of offsite power by itself, and a)

Verifying de-energization of the emergency busses and load shedding from the emergency busses.

b)

Verifying the diesel starts on the auto-start signal, energizes the emergency busses with permanently connected loads within 10 seconds and operates for greater than or equal to 5 minutes while its generator is loaded with the permanently connected loads.

After energization, the steady state voltage and frequency of the energency busses shall be maintained at 4360 1 436 volts and 60 1 1.2 Hz during this test.

5.

Verifying that on an ESF test signal, without loss of offsite l

power, the diesel generator starts on the auto-start signal and operates on standby for greater than or equal to 5 minutes.

The steady-state generator voltage and frequency shall be 4360 2 436 volts and 60 21.2 Hz within 10 seconds after the auto-start signal; the gerarator voltage and fregency shall be maintained within these limits during this test.

6.

Deleted 7.

SimulatingalossofoffsitepowerinconjunctionwithanESF test signal, and a)

Verifying de-energization of the emergency busses and load shedding from the emergency busses, b)

Verifying the diesel starts on the auto-start signal, energizes the emergency busses with permanently connected loads within 10 seconds, energizes the auto-connected emergency (accident) loads through the load sequence end operates for greater than or equal to 5 minutes while its generator is loaded with the emergency loads. After loading, the steady state voltage and frequency of the emergency busses shall be maintained at 4360 1 436 volts and 60 + 1.2/-0.3 Hz during this test.

c)

Verifying that all automatic diesel generator trips, except engine overspeed, generator differential, and low-low lube oil pressure, are automatically bypassed.

1

-SAN ONOFRE-UNIT 3 3/4 8-4 AMENDMENT NO. AP

.I

.=

~ *-

j ELECTRICAL' POWER SYSTEMS ONSITE POWER DISTRIBt 1N SYSTEMS

{

SHUTDOWN QP".TINGCONDITIONFOROPERATION 3.8.3.2, As'a minimum, the following electrical busses shall be energized in l

the specified manner:

a.

One division of A.C. Emergency Buses consisting of one 4160-volt and one 480-volt A.C. Emergency Bus.

b.

2 120 volt A.C. Vital Busses energized from their associated inverters connected to their respective D.C. Busses.

c.

2 -- 125 volt D.C. Busses energized from their associated battery banks.

APPLICABILI1Y: MODES 5 and 6 ACTION:

-With any of the above required electrical busses not energized in the required manner, immediately suspend all operations involving CORE ALTERATIONS, positive reactivity changes, or movement of irradiated fuel, initia A corrective action to energize the required electrical busses in the specified n oner as soon as possible.

SURVEILLANCE REQUIREMENTS 4.8.3.2 The specified busses shali be determined energized in the required manner at least once per 7 days by verifying correct breaker alignment and indicated voltage on the busses.

l l

SAN ONOFRE-UNIT 3 3/4 8-15 l

f REISSUED'8/25/S9 1

ELECTRICAL POWER SYSTEMS l

3/4.8.4 ELECTRICAL EQUIPMENT PROTECTIVE DEVICES CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES LIMITING CCNDITION FOR OPERATION 3.8.4.1 All containment penetration conductor overcurrent protective devices shown in Table 3.8-1 shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3 and 4.

ACTION:

With one or more of the above required containment penetration conductcr overcurrent protective device (s) inoperable:

Restore the protective device (s) to OPERABLE status or de energize a.

the circuits (si by tripping the associated backup circuit breaker or racking out ur removing the inoperable circuit breaker within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the affected system or component inoperable, and verify the backup circuit breaker to be tripped or the inoperable circuit breaker racked out, or removed, at least once per 7 days thereafter; the provisions of Specification 3.0.4 are not applicable to overcurrent devices in circuits which have their backup circuit breakers tripped, their inoperabic circuit breakers racked out,or removed, 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 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 4.8.4.1 All containment penetration conductor ove current protective devices shown in Table 3.8-1 shall be demonstrated OPERABLE:

a.

At least once per refueling interval:

I 1.

By verifying that the medium voltage (4-15 KV) circuit breakers are OPERABLE by selecting, on a rotating basis, at least 10% of the circuit breakers of each voltage level, and performing the following:

(a) A CHANNEL CALIBRATION of the associated protective relays, and (b) An integrated system functional test which includes simulated automatic actuation-of the system and verifying that each relay and associated circuit breakers and control circuits function as designed.

SAN ONOFRE-UMIT 3 3/4 8-16 AMENDMENT NO.63

{

3

REISSUED 6/25/89 t

ELECTRICAL POWER SYSTEMS i

i MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS LIMITING COWDITION FOR OPERATION l

3.8.4.2 The thermal overload protection shall be bypassed by a bypass device integral with the motor starter of each valve listed in Table 3.8.2.

APPLICABILITY:

Whenever the motor operated valve is required to be OPERABLE.

ACTION:

With the thermal overload protection not bypassed by the integral bypass device, bypass the thermal overload protection within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or declare the affected valve (s) inoperable and apply the appropriate ACTION Statement (s) for the affected valve (s).

SURVEILLANCE REQUIREMENTS 4.8.4.2 The above required thermal overload protection shall be verified to be bypassed by integral bypass devices:

At least once per refueling interval, a.

l b.

Following maintenance on the valve motor starter, and c.

Following any periodic testing during which the thermal overload device was temporarily placed in force.

1 SAN ONOFRE-UNIT 3 3/4 8-31 AMENDMENT NO. 63 l

-. - _ ~ _ _

~.

k TABLE 3.s>2 MOTOR OPERATED VALVES THERMAL OVERLOAD l-PROTECTION BYPASS DEVICES PERMANENTLY BYPASSED VALVE NUMBER FUNCTION HV-9339 Shutdown cooling flow from reactor coolant loop 2 HV-9340 SI tank T008 to reactor coolant loop 1A HV-9370 SI tank T010 to reactor coolant loop 2B HV-9347 SI pump minimum recirculation HV-9322 LPSI Header to reactor coolant loop 1A HV-9331 LPSI Header to reactor coolant loop 2B HV-9348 SI pump minimum recirculation HV-9323 HPSI Header #2 to reactor coolant loop 1A HV-9332 HPSI Header #2 to reactor coolant loop 2B HV-9217 RCP bleed off to volume control tank - cont. isol.

HV-9326 HPSI Header #2 to reactor coolant loop 1B HV-9329 HPSI Header #2 to reactor coolant loop 2A HV-7258 Waste gas surge tank header containment isolation HV-0508 Reactor coolant hot leg #1 sample containment isolation HV-0517 Reactor coolant hot leg #2 sample containment isolation 1

HV-9368 Shutdown HX E003 to containment spray header #2 HV-0510 Pressurizer vapor sample containment isolation HV-0512 Pressurizer surge line liquid sample containment isolation HV-9950 Containment purge outlet to exhaust unit A060 - cont. isol.

HV-9917 Hydrogen purge exhaust unit A08L inlet - containment isol.

EV-9946 Hydrogen purge supply unit A080 discharge - containment isol.

SAN ONOFRE-UNIT 3 3/4 8-32 I

ML20246J032

Text

Attachment:

Attachment:

Navigation menu

Search