ML20198H334
| ML20198H334 | |
| Person / Time | |
|---|---|
| Site: | San Onofre  |
| Issue date: | 05/16/1986 |
| From: | Knighton G Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20198H340 | List: |
| References | |
| TAC-54694, TAC-54695, TAC-54710, TAC-54711, TAC-57276, TAC-57277, NUDOCS 8605300280 | |
| Download: ML20198H334 (52) | |
Text
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l UNITED STATES f-
n NUCLEAR REGULATORY COMMISSION h
WASHING TON, D. C. 20555 e
N.... /
4 j
l SOUTHERN CALIFORNIA EDIS0N COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RIVERSIDE, CALIFORNIA 1
l THE CITY OF ANAHEIM, CALIFORNIA DOCKET NO. 50-361 i
SAN ONOFRE NUCLEAR GENERATING STATION, UNIT 2
}
AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 46 License No. NPF-10 l
1.
The Nuclear Regulatory Comission (the Comission) has found that:
A.
The applications for amendment.to the license for San Onofre Nuclear Generating Station, Unit 2 (the facility) filed by the Southern
^
i California Edison Company on behalf of itself and San Diego Gas and i
Electric Com California (pany, The City of Riverside and the City of Anaheim, licensees) 1984, comply with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's regulations as set forth in 10 CFR Chapter I; i
B.
The facility will operate in conformity with the application, as i
amended, the provisions of the Act, and the regulations of the-Commission; i
C.
There is reasonable assurance:
(1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be j
conducted in compliance with the Comission's regulations set j
forth in 10 CFR Chapter I;
- )
i' D.
The issuance of this license amendment will not be inimical to the 1
common defense and security or to the' health and safety of the i
public; j
i E.
The issuance of this amendment is in accordance with 10 CFR Part 51 j
of the Comission's regulations and all applicable requirements have been satisfied.
4
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soogi aoocn
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- 2.
Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this 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. 46, are hereby incorporated in the license.
SCE shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
This amendment is effective immediately and is to be fully implemented within 30 days of the date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION George
. Knighton irector PWR Project Directorate No. 7 Division of PWR Licensing-B
Attachment:
Changes to the Technical Specifications Date of Issuance:
May 16, 1986 G
h m
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May 16, 1986 ATTACHMENT TO LICENSE AMENDMENT NO. 46 FACILITY OPERATING LICENSE NO. NPF-10 DOCKET NO. 50-361 Replace the following pages of the Appendix A Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contains verticals line indicating the area of change. Also to be replaced are the following overleaf pages to the amended pages.
Amendment Pages Overleaf Pages 3/4 3-28 3/4 3-27 3/4 3-29 3/4 3-30 3/4 6-1 3/4 6-2 3/4 6-18 3/4 6-17 3/4 6-19 3/4 6-20 3/4 6-21 3/4 6-27.
3/4 6-23 3/4 6-24 3/4 6-25 3/4 6-26 3/4 7-9 3/4 7-10 B 3/4 6-4 8 3/4 6-3 B 3/4 6-5
,,TADLE 3.3 -
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E!GINEERED SAFETY FEATURES. RESPONSE TIMES RESP 0ftSE TIME (SEC) f INITItTING SIG::AL At:D FUtlCTION
, 1.
Manual s.
SIAS Seir'.y Injection Not Applicable Control Room Isolation flot Applicable Con.ain. tent Isolction (3)
Not Applicable Containment Emergency Cooling Not Applicable
~
~b.
CSAS Not Applicable Containment Spray c.
CIAS Centainment Isolation Not Applicable d.
MSIS Main Steam Isolation Not Applicable e.
RAS Containment 5 ump Recirculation Not Applicable tt CCAS Containment Emergency Cooling Not Applicable g.
EFAS Auxiliary Feedwater Not Appl.icable
.h.
CRIS Not Applicable Control Room Isolation i.
TGIS Toxic Gas Isolation ot tpplicable i
j.
FHIS Fuel Handling Building Isolation Nbt Applicable,
k.
CPIS
- Con.ainment Purge Isolation Not Applicable p.
SAN 0 CFRE-UNIT 2 3/4 3-27
6 f
Table 3.3-5 (continued)
INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) 2.
Pressurizer Pressure-Low a.
SIAS (1) Safety Injection (a) High Pressure Safety Injection 31.2*
(b) Low Pressure Safety Injection 41.2*
(c) Charging Pumps 31.2*
(2) Control Room Isolation Not Applicable (3) Containment Isolation (NOTE 3) 11.2* (NOTE 2)
(4) Containment Spray (Pumps) 25.6*
(5) Containment Emergency Cooling (a) CCW Pumps 31.2*
(b) CCW Valves (Note 4b) 23.2*
(c) Emergency Cooling Fans 21.2*
3.
Containment Pressure-High I
a.
SIAS (1) Safety Injection (a) High Pressure Safety Injection 41.0*
(b) Low Pressure Safety Injection 41.0*
(2) Control Room Isolation Not Applicable (3) Containment Spray (Pumps) 25.4*
(4) Containment Emergency Cooling (a) CCW Pumps 31.0*
(b) CCW Valves (Note 4b) 23.0*
(c) Emergency Cooling Fans 21.0*
b.
CIAS (1) Containment Isolation-10.9* (NOTE 2)
(2) Main Feedwater Isolation 10.9 and Backup Isolation Valves (HV 4048, HV 4052, HV 1105, HV 1106, HV 4047, HV 4051)
(3) CCW Valves (Note 4a) 20.9 (4) Mainsteam Isolation Valves (HV 8204, 6.9 HV 8205)
(5) Minipurge Isolation Valves 5.9 4.
Containment Pressure - High-High j
CSAS Containment Spray 23.0*
SAN ONOFRE - UNIT 2 3/4 3-28 AMEN 0 MENT NO. 46
l Table 3.3-5 (Continued) 1 INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) l 5.
Steam tienerator Pressure - Low MSIS I
(1) Main Steam Isolation (HV8204, HV8205) 6.9 (2) Main Feedwater Isolation (HV4048, HV4052) 10.9 i
(3) ' Steam, Blowdown and Sample Isolation 20.9 I
(HV8419,HV8421) j (HV4053, HV4054, HV4057, HV4058)
(4) Auxiliary Feedwater Isolation (NOTE 7) 40.9 (HV4705, HV4713, HV4730, HV4731)
(HV4706,HV4712,HV4714,HV4715) 6.
Refueling Water Storage Tank - Low RAS
=
j
{
(1) Containment Sump Valves Open 50.7*
I 4
j 7.
4.16 kv Emergency Bus Undervoltage l
LOV (loss of voltage and degraded voltage)
Figure 3.3-1 l
8.
Steam Generator Level - Low (and No l
Pressure-Low Trip)
EFAS i
(1) Auxiliary Feedwater (AC trains) 52.7*/52.7**
l (2) Auxiliary Feedwater (Steam /DC train) 42.7 (NOTE 6) 9.
Steam Generator Level - Low (and AP - High)
I i
EFAS l
(1) Auxiliary Feedwater (AC trains) 52.7*/52.7**
l (2) Auxiliary Feedwater (Steam /DC train) 42.7 (NOTE 6) 1 l
10.
Control Room Ventilation Airborne Radiation j
CRIS (1) Control Room Ventilation
. Emergency i
Mode Not Applicable
)
11.
Control Room Toxic Gas (Chlorine)
I l
TGIS (1) Control Room Ventilation - Isolation l
Mode 16 (NOTE 5) 12.
Control Room Toxic Gas (Ammonia)
TGIS Control Room Ventilation - Isolation Mode 36 (NOTE 5) b l
SAN ONOFRE - UNIT 2 3/4 3-29 AMEN 0 MENT NO. 46 l
Table 3.3-5 (Continued)
INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) 13.
Control Room Toxic Gas (Butane / Propane)
TGIS Control Room Ventilation -
Isolation Mode 36 (NOTE 5) 14.
Control Room Toxic Gas (Carbon Dioxide)
TGIS
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Control Room Ventilation -
Isolation Mode 36 (NOTE 5) 15.
Fuel Handling Building Airborne Radiation FHIS Fuel Handling Building Post-Accident Cleanup Filter System Not Applicable 16.
Containment Airborne Radiation CPIS Containment Purge Isolation 2 (NOTE 2) 17.
Containment Area Radiation l
CPIS Containment Purge Isolation 2 (NOTE 2)
NOTES:
1.
Response times include movement of valves and attainment of pump or blower discharge pressure as applicable.
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2.
Response time includes emergency diesel generator starting delay (applicable to A.C. motor-operated valves other than containment purge valves), instrumentation and logic response only.
Refer to Table 3.6-1 for containment isolation valve closure times.
3.
All CIAS-actuated valves except MSIVs, MFIVs, and CCW Valves 2HV-6211, 2HV-6216, 2HV-6223 and 2HV-6236.
4a.
CCW noncritical loop isolation Valves 2HV-6212, 2HV-6213, 2HV-6218, and 2HV-6219 close.
4b.
Containment emergency cooler CCW isolation Valves 2HV-6366, 2HV-6367, 2HV-6368, 2HV-6369, 2HV-6370, 2HV-6371, 2HV-6372, and 2HV-6373 open.
5.
Response time includes instrementation, logic, and isolation damper closure times only.
6.
The provisions of Specification 4.0.4 are not applicable for entry into MODE 3.
7.
Include HV4762 and HV4763 following implementation of DCP 195J.
Emergency diesel generator starting delay (10 sec.) and sequence loading delays for SIAS are included.
Emergency diesel generator starting delay (10 sec.) is included.
SAN ONOFRE - UNIT 2 3/4 3-30 AMEN 0 MENT NO. 46
0 4
3/4.6 CONTAINMENT SYST MS 3/4.6.1 PRIMARY CONTAINMENT CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION
- 3. 6.1.1 Primary CONTAINMENT INTEGRITY shall be maintained.
APPLICABILITY:
MODES 1, 2, 3 and 4.
ACTION:
Without primary CONTAINMENT INTEGRITY, restore CONTAINMENT INTEGRITY within one hour or be in at least HOT STAND 8Y within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUT 00WN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
SURVEILLANCE REQUIREMENTS I
4.6.1.1 Primary CONTAINMENT INTEGRITY shall be demonstrated:
a.
At least once per 31 days by verifying that all penetrations
- listed in Sections A, B and C of Table 3.6-1 not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or automatic valves secured ** in their positions, except as provided in Table 3.6-1 of Specification 3.6.3.
I b.
By verifying that each containment air lock is in compliance with the requirements of Specification 3.6.1.3.
c.
After each closing of each penetration subject to Type B testing, except containment air locks, if opened following a Type A or B test, by leak rate testing the seal with gas at P, 55.7 psig and verifying that when the measured leakage rate for these seals is added to the leakage rates determined pursuant to Specifica-tion 4.6.1.2.d for all other Type B and C penetrations, the combined leakage rate is less than 0.60 L,,
- Except valves, blind flanges, and automatic valves which are located inside the containn.ent and are locked, sealed or otherwise secured in the closed position.
These penetrations shall be verified closed during each COLD SHUTDOWN except that such verification need not be performed more often than 1
once per 92 days.
I
- Locked, sealed or otherwise prevented from unintentional operation.
SAN ONOFRE-UNIT 2 3/4 6-1 AMEN 0 MENT NO. 46 c
1 CONTAINMENT SYSTEMS CONTAINMENT LEAKAGE LIMITING CONDITION FOR OPERATION 3.6.1.2 Containment leakage rates shall be limited to:
a.
An overall integrated leakage rate of:
containmentairper24Ro,urs.10percentbyweightofthe 1.
Less than or equal to L 0
at P, 55.7 psig, or 3
2.
Less than or equal to L, 0.05 per::ent by weight of the containmentairper24IloursatareducedpressureofP, g
27.9 psig.
b.
A combined leakage rate of less than 0.60 L, for all penetrations ar.d valves subject to Type B and C tests, when pressurized to P,.
APPLICABILITY:
MODES 1, 2, 3 and 4.
ACTION:
With either (a) the measured overall integrated containment leakage rate exceeding 0.75L*allpenetrItionsandvalvessubjecttoTypesBandCtests or 0.75 L, as applicable, or (b) with the meacured combined leakage rate for exceeding 0.60 L,' restore the overall integrated leakage rate to less than or equal to 0.75 L,or less than or equal to 0.75 L, as applicable, and the combinedleakag8rateforallpenetrationsandvbivessubjecttoType8andC tests to less than 0.60 L temperature above 200*F., prior to increasing the Reactor Coolant System SURVEILLANCE REQUIREMENTS 4.6.1.2 The containment leakage rates shall be demonstrated at the following test schedule and shall be determined in conformance with the criteria specified in Appendix J of 10 CFR 50 using the methods and provisions of ANSI N45.4 - 1972:
a.
Three Type A tests (Overall Integrated Containment Leakage Rate) shall be conducted at 40 + 10 month intervals during shutdown at either P (27.9 psig) during each 10 year service $er(55.7 psig) or at PThethirdtehtofeachsetshallbeconducted iod.
during the shutdown for the 10 year plant inservice inspection.
Prior to the Type A tests a visual inspection shall be conducted in accordance with Specification 4.6.1.6 to demonstrate the contain-ment structural integrity.
l SAN ONOFRE-UNIT 2 3/4 6-2 i
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CONTAINMENT SYSTEMS j
CONTAINMENT COOLING SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.3 Two independent groups of contai.nment cooling fans shall be OPERABLE vith two fan systems to each group.
APPLICABILITY:
MODES 1, 2, 3 and 4.
ACTION:
With one group of the above required containment cooling fans a.
incperable and both containment spray systems OPERABLE, restore the inoperable group of cooling fans to.0PERABLE status within 7 days or i
be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD i
SHUT 00WN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
b.
With two groups of the above required containment cooling fans 1
inoperable, and both containment spray systems OPERABLE, restore at i
least one group of cooling fans to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> cr be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD J
SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
Restore both above required f\\
groups of cooling f ans to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in a
COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
\\
c.
With one group of the above required containment coolin'g fans inoperable and one containment spray system inoperable, restore the inoperable spray system to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
Restore the inoperable group of containment cooling fans to OPERABLE status within 7 days of initial 1
loss or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUT 00WN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
SURVEILLANCE REOUIREhENTS i
n 4.6.2.3 Each group of containment cooling fans shall be demonstrated 1
OPERABLE:
a.
At least once per 31 days by:
i 1.
Starting each fan group from the control room and verifying that each fan group operates for at least 15 minutes, i
2.
Verifying a cooling water flow rate of greater-than or equal to 2000 gpm to each cooler,
?I b.,
At least once per 18 months by verifying that each fan group starts l
automatically on a Containment Cooling Actuation test signal.
i SAN ONOFRE-UNIT 2 3/4 6-17
CONTAINMENT SYSTEMS 3/4.6.3 CONTAINMENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.3 The containment isolation valves specified in Table 3.6-1 shall be OPERABLE with isolation times as shown in Table 3.6-1.
APPLICABILITY:
MODES 1, 2, 3 and 4.
ACTION:
1.
With one or more of the isolation valve (s) specified in Section A, B and C of Table 3.6-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration
- that is open and either:
a.
Restore the inoperable valve (s) to OPERABLE status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, or b.
Isolate each affected penetration within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> by use of at least one automatic valve secured ** in the isolation position, or one closed manual valve or blind flange, or c.
Be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />, d.
The provisions of Specification 3.0.4 are not applicable.
2.
With one or more of the valves specified in Section D of Table 3.6-1 inoperable, the appropriate ACTION statement (s) of those Limiting Conditions for Operation pertaining to the valve (s) or system in which it is installed shall be applicable.
SURVEILLANCE REQUIREMENTS 4.6.3.1 The isolation valves specified in Section A and B of Table 3.6-1 shall be demonstrated OPERABLE prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by performance of testing pursuant to Specification 4.0.5.
Valves secured ** in their actuated position are considered OPERABLE pursuant to this specification.
- Any flow path from the atmosphere or a piping system inside of containment to the atmosphere or a piping system outside of containment.
Each flow path is considered as a scparate " penetration".
- Locked, sealed or otherwise prevented from unintentional operation.
l SAN ONOFRE-UNIT 2 3/4 6-18 AMENDMENT NO. 46 l
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4 CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 4.6.3.2 Each isolation valve (except check valves) specified in Section A and B of Table 3.6-1 shall be demonstrated OPERABLE during the COLD SHUTDOWN or REFUELING MODE at least once per 18 months by verifying that on an ESFAS test signal, each isolation valve actuales to its isolation position.
4.6.3.3 Theisolationtimeofeachpoweroperatedorautomaticvalvh(except check valves) in Section A and B of Table 3.6-1 shall be determined to be within its limit when tested purs'uant to Specification 4.0.5.
4.6.3.4 The manual isolation valves specified in Section C of Table 3.6-1 shall be demonstrated OPERABLE in accordance with Specifications 4.6.1.1.a and 4.6.1.2.d.
4.6.3.5 The isolation valves specified in Section D of Table 3.6-1 shall be demonstrated OPERABLE as required by Specification 4.0.5 and surveillance re-quirements associated with those Limiting Conditions for Operation pertaining to each valve or system in which it is installed.
Valves secured ** in the ESFAS actuated position are considered OPERABLE pursuant to this specification.
J I
4 P
I
- Locked, sealed or otherwise prevented from unintentional operation.
SAN ONOFRE-UNIT 2 3/4 6-19 AMENDMENT N0. 46 O
t 1
i 4
l TABLE 3.6-1 CONTAINMENT ISOLATION VALVES l
MAXIMUM PENETRATION ISOLATION I
NUMBER VALVE NUMBER FUNCTION TIME (SEC)
A.
AUTOMATIC CONTAINMENT ISOLATION 1
HV-0510 Pressurizer steam space sample 40 1
HV-0511 Pressurizer steam space sample 40 2
TV-9267 Letdown line to letdown heat exchanger 40 2
HV-9205 Letdown line to letdown heat exchanger 40 t
4 HV-0508 Reactor coolant loops hot leg sample 40 4
HV-0509 Reactor coolant loops hot leg sample 40 i
4 HV-0517 Reactor coolant loops hot leg sample 40 6
HV-9334 Safety injection drain to RWST 40 7
HV-9217 Reactor coolant pump seal bleed off 40 7
HV-9218 Reactor coolant pump seal bleed off 40 11 HV-7911 Demineralized water to service station and sump pump 40 11 3"-236-C-675 Demineralized water to service station and sump pump check valve NA 12 HV-0512 Pressurizer surge line sample 40 1
12 HV-0513 Pressurizer surge line sample 40 13 HV-5803 Containment sump pump discharge 40 13 HV-5804 Containment sump pump discharge 40 14 HV-5686 Fire protection 40 14 4"-061-C-681 Fire protection check valve NA 16C HV-7805 Containment air radioactivity monitor inlet 1
16C HV-7810 Containment air radioactivity monitor inlet 1
20 2"-573-C-611 Quench tank makeup check valve NA 21 2"-017-C-627 Service air supply line check valve NA 22 HV-5388 Instrument air supply line 40 22 1 1/2"-016-C-617 Instrument air supply line check valve NA l 23A HV-5437 LP N to containment 40 i
2 23A 3/4"-002-C-611 LP N to containment check valve NA l 2
26 HV-7512 Reactor coolant drain tank pump discharge 40 26 HV-7513 Reactor coolant drain tank pump discharge 40 27C HV-7806 Containment air radioactivity monitor outlet 1
l 27C HV-7811 Containment air radioactivity monitor outlet 1
30A HV-7802 Containment air radioactivity monitor outlet 1
30A HV-7803 Containment air radioactivity monitor outlet 1
i 300 HV-7801 Cuntainment air radioactivity monitor outlet 1
30B HV-7800 Containment air radioactivity monitor outlet 1
30B HV-7816 Containment air radioactivity monitor outlet 1
30C HV-0516 Quench tank and drain tank gas sample 40 i
30C HV-0514 Quench tank and drain tank gas sample 40 30C HV-0515 Quench tank and drain tank gas sample 40 42 HV-6211 Component cooling water inlet 40 l
)
42 HV-6223 Component cooling water inlet 40 43 HV-6236 Component cooling water outlet 40 SAN ONOFRE - UNIT 2 3/4 6-20 AMEN 0 MENT NO. 46
TABLE 3.6-1 CONTAINMENT ISOLATION VALVES (Continued)
MAXIMUM PENETRATION ISOLATION
~
NUMBER VALVE NUMBER FUNCTION TIME (SEC)
A.
AUTOMATIC CONTAINMENT ISOLATION (Cont.)
43 HV-6216 Component cooling water outlet 40 45 HV-9900 Containment normal A/C chilled water inlet 40 45 HV-9920 Containment normal A/C chilled water inlet 40 46 HV-9971 Containment normal A/C chilled water outlet 40 46 HV-9921 Containment normal A/C chilled water outlet 40 47 HV-7258 Containment waste gas vent header 40 47 HV-7259 Containment waste gas vent header 40 68 2"-129-A-554 Charging I'ine to auxiliary spray check valve NA l
77 HV-5434 Nitrogen supply to safety iajection tanks 40 77 2"-108-C-627 Nitrogen supply to safety injection tanks check valve NA B.
CONTAINMENT PURGE (CPIS) 18 HV-9949**
Containment purge inlet (normal) 12 18 HV-9948**
Containment purce inlet (normal) 12 18 HV-9821 Containment mini purge inlet 5
18 HV-9823 Containmentamini purge inlet 5
19 HV-9950**
Containment purge outlet (nomal) 12 19 HV-9951**
Containment purge. outlet (normal)
'12 19 HV-9824 Containment mini purge outlet 5
19 HV-9825 Containment mini purge outlet 5
C.
MANUAL
- 6 2"-0?9-C-334 Safety injection drain to RWST NA 9
HV-9337#@
Shutdown cooling to LPSI pumps NA NA 9
HV-9377#@
Shutdown cooling to LPSI pumps 9
HV-9336#@
Shutdown cooling to LPSI pumps NA 9
HV-9379#@
Shutdowa cooling to LPSI pumps NA 10B 3/4"-038-C-396 Integrated leak rate test pressure sensor NA 10B 3/4"-039-C-396 Integrated leak rate test pressure sensor-NA 16A HV-0500 Post LOCA' hydrogen monitor NA 16A HV-0501 Post LOCA hydrogen monitor NA 16B H7-0502 Post LOCA hydrogen monitor NA 16B HV-0503 Post LOCA hydrogen monitor 20 2"-321-C-376 Quench tank makeup NA NA 1
Manual valves may be opened on an intermittent basis under administrative control.
- Power to the valve removed in accordance with Specification 3.6.1.7.
- Not' subject to Type C leakage tests.
@ Shutdown cooling valves may be opened in MODE 4.
s SAN ON0FRE - UNIT'2 3/4 6-21 AMEN 0 MENT NO. 46 y
V o
TABLE 3.6-1 CONTAINMENT ISOLATION VALVES (Continued)
MAXIMUM PENETRATION ISOLATION NUMBER VALVE NUMBER FUNCTION TIME (SEC)
C.
MANUAL * (Cont.)
I 21 2"-055-C-387 Service air supply line NA 25 10"-100-C-212 Refueling canal fill and drain NA 25 10"-101-C-212 Refueling canal fill and drain NA 31 HV-9946 Containment hydrogen purge inlet NA 31 HCV-9945 Containment hydrogen purge inlet NA 68 2"-130-C-334 Charging line to auxiliary spray NA l 70 2"-037-C-387 Auxiliary steam inlet to utility stations NA 70 2"-038-C-387 Auxiliary steam inlet to utility stations NA l 74 HV-9917 Containment hydrogen purge outlet NA 74 HCV-9918 Containment hydrogen purge outlet NA I
0.
OTHER***
1 3
3"-018-A-551#
High pressure safety injection NA 3
HV-9323#
High pressure safety injection NA 3
HV-9324#
High pressure safety injection NA 5
3"-019-A-551#
High pressure safety injection NA 5
HV-9326#
High pressure safety injection NA 5
HV-9327#
High pressure safety injection NA 8
2"-122-C-554 Charging line to regenerative heat exchanger NA 8
HV-9200 Charging line to regenerative heat exchanger NA 10A HV-0352A#
Containment pressure detectors NA 17 HV-4058#*
Steam generator secondary coolant sample NA 27A HV-0352D#
Containment pressure detectors NA 32 HV-8202#
Mainsteam isolation bypass NA 33 HV-8203#
Mainsteam isolation bypass NA 36 HV-4054#*
Steam generator blowdown -
NA 37 HV-4053#*
Steam generator blowdown NA 39 3"-020-A-551#
High pressure :afety injection NA 39 HV-9329#
High pressure safety injection NA 39 HV-9330#
High pressure safety injection NA 40A HV-0352B#
Containment pressure detectors NA 41 3"-021-A-551#
High pressure safety injection NA 41 HV-9332#
High pressure safety injection NA Manual valves may be opened on an intermittent basis under administrative control.
CR0 Valves secured in the ESFAS actuated position are considered OPERABLE pursuant to I
this specification.
Not subject to Type C leakage tests.
~
1 e
SAN ONOFRE - UNIT 2 3/4 6-22 AMENDMENT N0.46
TABLE 3.6-1 CONTAINMENT ISOLATION VALVES (Continued)
MAXIMUM PENETRATION ISOLATION 4
NUMBER VALVE NUMBER FUNCTION TIME (SEC)
D.
OTHER*** (Cont.)
I 41 HV-9333#
High pressure safety injection NA 44 HV-4057#*
Steam generator secondary coolant sample NA 48 8"-072-A-552#
Low pressure safety injection NA 48 HV-9322#
Low pressur.e safety injection NA 49 8"-073-A-552#
Low pressure safety injection NA 49 HV-9325#
tow pressure safety injection NA 50 8"-074-A-552#
Low pressure safety injection NA 50 HV-9328#
Low pressure safety injection NA 51 8"-075-A-552#
Low pressure safety injection NA 51 HV-9331#
Low pressure safety injection NA 52 8"-004-C-406 Containment spray inlet NA 52 HV-9367 Containment spray inlet NA i
53 8"-006-C-406 Containment spray inlet NA 53 HV-9368 Containment spray inlet NA 54 HV-9304#
Containment emergency sump recirculation NA 54 HV-9302#
Eontainment emergency sump recirculation NA 55 HV-9305#
Containment esergency sump recirculation NA 55
,HV-9303#
Containment emergency sump recirculation NA 56 HV-6366 Containment emergency A/C cooling water inlet NA 57 HV-6372 Containment emargency A/C cooling water inlet NA 58 HV-6368 Containment emergency A/C cooling water inlet NA 59 HV-6370 Containme.nt emergency A/C cooting water inlet NA 60 HV-6369 Containment emargency A/C cooling water outlet NA 61 HV-6371 Containment emergency A/C cooling water outlet NA 62 Hv-6367 Containment emergency A/C cooling water outlet NA 63 HV-6373 Conta4rment energer,cy A/C cooling water outlet NA 67 3"-157-A-550 Hot leg injection NA 67 HV-9434 Hot leg injection NA 71 3"-158-A-550 Hot leg injection NA 71 HV-9420 Hot leg injection NA 73A HV-0352C#
Cont.ainment pressure detectors NA 1
=
0 Manual valves may be opened on an intermittent basii under administrative coritrol.
So Valves secured in the ESEAS actuated position are considered OPERABLE pursuant to this specification.
Not subject to Type C leakage tests.
J SAN ON0FRE - UNIT 2 3/4 6-23 AMENDNdNT NO.46 l
l
DELETED INTENTIONAlt.Y i
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i 9
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SAN ONOFRE-UNIT 2 3/4 6-24 AMENDMENT NO. 46
DELETED INTENTIONALLY l
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SAN ON0FRE-UNIT 2 3/4 6-25 AMEN 0 MENT NO. 46 L
CONTAINMENT SYSTEMS 3/4.6.4 COMBUSTIBLE GAS CONTROL HYDROGEN MONITORS LIMITING CONDITION FOR OPERATION 3.6.4.1 Two independent containment hydrogen monitors shall be OPERABLE.
APPLICABILITY:
MODES 1 and 2.
ACTION:
a.
With one hydrogen monitor inoperable, restore the inoperable monitor to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
b.
With two hydrogen monitors inoperable, restore at least one hydrogen monitor to OPERABLE within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
c.
With one hydrogen monitor inoperable, the provisions of Specifica-tion 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.6.4.1 Each hydrogen moni, tor shall be demonstrated OPERABLE by:
3 a.
The performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days,
- and, b.
At least once per 92 days on a STAGGERED TEST BASIS, by performing a l
CHANNEL CALIBRATION using the following sample gases:
t i
i)
Nitrogen, and ii) Four volume percent hydrogen, balance nitrogen.
G SAN ONOFRE-UNIT 2 3/4 6-26 AMENDMENT NO. 46
e A
8 PLANT SYSTEMS MAIN STEAM LINE ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.7.1.5 Each main steam line isolation valve shall be OPERABLE.
APPLICABILITY:
MODES 1, 2 and 3.
ACTION:
MODE 1 With one main steam line isolation valve inoperable but open, POWER OPERATION may continue provided the inoperable valve is restored to OPERABLE status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />; otherwise, reduce power to less than or equal to 5 percent RATED THERMAL POWER within the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
MODES 2 With one main steam line isolation valve inoperable, and 3 subsequent cperation in MODES 2 or 3 may proceed provided:
a.
The isolation valve is maintained closed.
b.
The provisions of Specification 3.0.4 are not applicable.
Otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.7.1.5 Each main steam line isolation valve shall be demonstrated OPERABLE by verifying full closure within 6.0 seconds when tested pursuant to
}
Specification 4.0.5.
SAN ONOFRE-UNIT 2 3/4 7-9 AMENDMENT NO. 46
4 PLANT SYSTEMS 7
.)
'(
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:
Reduce the steam generator pressure of the applicable side to less a.
,than or equal to 200 psig within 30 minutes, and b.
Perform an engineering evaluation to determine the effect of the overpressurization on the structural integrity of the steam generator.
Determine that the steam generator remains acceptable for continued operation prior to increasing its temperatures above 200*F.
i SURVEILLANCE REQUIREMENTS 4.7.2 The pressure in each side of the steam gen: rat _ prs shall-be determined to be less than 200 psig at least once per hour when the temperature of either the primary or secondary coolant is less than 70*F.
e SAN ONOFRE-UNIT 2 3/4 7-10 a
CONTAINMENT SYSTEMS k
BASES 3/4.6.1.7 CONTAINMENT VENTILATION SYSTEM The 42-inch containment purge supply and exhaust isolation valves are required to be closed during plant operation since these valves have not been demonstrated capable of closing during a LOCA or steam line break accident.
Maintaining these valves closed during plant operations ensures that excessive quantities of radioactive materials will not be released via the containment purge system.
To provide assurance that the 42-inch valves cannot be inadvert-ently opened, they are sealed closed in accordance with Standard Review Plan 6.2.4 which includes mechanical devices to seal or lock the valve closed or prevent power from being supplied to the valve operator.
The use of the containment purge lines is restricted to the 8-inch purge supply and exhaust isolation valves since, unlike the 42-inch valves, the 8-inch valves will close during a LOCA or steam line break accident and there-fore the site boundary dose guidelines of 10 CFR Part 100 would not be exceeded in the event of an accident during purging operations.
The design of the 8-inch purge supply and exhaust isolation valves meets the requirements of Branch Technical Position CSB 6-4, " Containment Purging During Normal Plant Operations."
Leakage integrity tests with a maximum allowable leakage rate for purge supply and exhaust isolation valves will provide early indication of resilient material k
seal degradation and will allow the opportunity for repair before gross leakage failure develops.
The 0.60 L leakage limit shall not be exceeded when the leakageratesdeterminedbytfleleakageintegritytestsofthesevalvesare added to the previously determined total for all valves and penetrations subject to Type B and C tests.
~
3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS 3/4.6.2.1 CONTAINMENT SPRAY SYSTEM The OPERABILITY of the containment spray system ensures that containment depressurization and cooling capability will be available in the event of a LOCA.
The pressure reduction and resultant lower containment leakage rate are consistent with the assumptions used in the accident analyses.
The containment spray system and the containment cooling system are redundant to each other in providing post accident cooling of the containment atmosphere.
However, the containment spray system also provides a mechanism for removing iodine from the containment atmosphere and therefore the time requirements for restoring an inoperable spray system to OPERABLE status have been maintained consistent with that assigned other inoperable ESF equipment.
O SAN ON0FRE-UNIT 2 B 3/4 6-3
e CONTAINMENT SYSTEMS BASES A
3/4.6.2.2 IODINE REMOVAL SYSTEM The OPERABILITY of the iodine removal system ensures that sufficient Na0H is added to the containment spray in the eventdef a LOCA.
The limits on Na0H volume and concentration' ensure that the solution recirculated with contain-ment after a LCCA has a pH value between 8.0 and 10.0 at the end of the Na0H injectionperiod.
This pH band minimizes the evolution of iodine and minimizes 4
the effect of chloride and caustic stress corrosion on mechanical systems and components.
The contained water volume limit includes an allowance for water not usable because of tank discharge line location or other physical character-i istics.
These assumptions are consistent with the iodine removal efficiency assumed in the accident analyses.
The 5 year Surveillance testing is intended to verify that no crystallization of the Na0H or other obstruction has occurred in the piping from the spray 1
additive tank to the suction of the containment spray pumps.
3/4.6.2.3 CONTAINMENT COOLING SYSTEM The OPERABILITY of the containment cooling system ensures that 1) the con-tainment air temperature will be maintained within limits during normal opera-tion, and 2) adequate heat removal capacity is available when operated in con-junction with the containment spray systems during post-LOCA conditions.
The containment cooling system and the containment spray system are redundant to each other in providing post accident cooling of the containment atmosphere.
As a result of this redundancy in cooling capability, the allowable out of ser-vice time requirements for the containment cooling system have been appropri-ately adjusted.
However, the allowable out of service time requirements for the containment spray system have been maintained consistent with that assigned other ' inoperable ESF equipment since the containment spray system also provides a mechanism for removing iodine from the containment atmosphere.
3/4.6.3 CONTAINMENT ISOLATION VALVES The OPERABILITY of the containment isolation valves ensures that the contain-ment atmosphere will be isolated from the outside environment in the event of a release of radioactive material'to the containment atmosphere and is consis-tent with the requirements of GDG 54 through 57 of Appendix A to 10 CFR 50.
Containment isolation within the time limits specified for those power operated isolation valves designed to close automatically upon a CIAS signal ensures that the release of radioactive material to the environment will be consistent-with the assumptions used in the analyses for a LOCA.
Such valves are listed i
in Sections A and B of Table 3.6-1 and Surveillance requirements to verify OPERABILITY of these valves are explicitly stated in 4.6.3.1 thru 4.6.3.3.
I Check valves located inside containment are considered OPERABLE provided their leak rate is within limits when tested pursuant to 10 CFR 50 Appendix J.
SAN ONONFRE - UNIT 2 B 3/4 6-4 AMENDMENT N0.46 i
_ _ _. - _ _ -, _ ~ - _ _ -. _. _ _...
_ ~,_
~.
I CONTAINMENT SYSTEMS BASES i
3/4.6.3 CONTAINMENT ISOLATION VALVES (Continued)
Section C of Table 3.6-1 contains a listing of manual valves that are normally closed and assumed to be closed under design basis accident conditions, but which may be opened intermittently for service, maintenance or test during normal operation provided adequate administrative controls are implemented to l
ensure operator action is taken to close such valves in the event of an 1
accident.
i i
All valves in Section A, B or C are considered OPERABLE for containment isola-t tion purpose if they are indeed locked, sealed or otherwise secured in the closed position and leakage through the affected flow path is shown to be within limits when tested pursuant to 10 CFR 50 Appendix J.
i Section D of Table 3.6-1 contains a listing of valves which operate automati-cally on an ESFAS signal to prevent or mitigate the consequences of the design 1
i basis accident.
Surveillar.ce requirement 4.6.1.1.a is not applicable to such i
valves.
The OPERABILITY of such valves is determined by ESFAS response time i
testing of Specification 3/4.3.2.
Valves in Section D that are locked, sealed or otherwise secured in their ESFAS actuated position will permit performance i
i of their safety function and are, therefore, considered OPERABLE pursuant to this specification.
+
4 3/4.6.4 COMBUSTIBLE GAS CONTROL j
The OPERABILITY of the equipment and systems required for the detection and control of hydrogen gas ensures that this equipment will be available to maintain the hydrogen concentration within containment below its flammable i
limit during post-LOCA conditions.
Either recombiner unit is capable of controlling the expected hydrogen generation associated with 1) zirconium-water reactions, 2) radiolytic decomposition of water and 3) corrosion of metals within containment.
These hydrogen control systems are consistent with the recommendations of Regulatory Guide 1.7, " Control of Combustible Gas Concentrations in Containment Following a LOCA", March 1971.
The containment dome air circulators are provided to ensure adequate mixing of the containment atmosphere following a LOCA.
The mixing action
]
of the containment dome air circulators combined with the containment spray system and the containment emergency fan coolers will prevent localized accumulations of hydrogen from exceeding the flammable limit.
1 f
l l
SAN ONONFRE - UNIT 2 B 3/4 6-5 AMENDMENT NO. 46
_. _. _.. _ _. -. ~. _... - - -. _ _. - _..., _.. _.
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UNITED STATES y,
g NUCLEAR REGULATORY COMMISSION f'
pj e ASHINGTON, D. C. 20555
/
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SOUTHERN CALIFORNIA EDIS0N COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RIVERSIDE, CALIFORNIA THE CITY OF ANAHEIM, CALIFORNIA DOCKET NO. 50-362 SAN ON0FRE NUCLEAR GENERATING STATION, UNIT 3 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.
License No. NPF-15 1.
The Nuclear Regulatory Commission (the Commission) has found that:
j A.
The application for amendment to the license for San Onofre Nuclear Generating Station, Unit 3 (the facility) filed by the Southern California Edison Company on behalf of itself and San Diego Gas and Electric Company, The City of Riverside and the City of Anaheim,
-California-(. licensees) dated January 25, April 27, and November 30, 1984, comply with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's regulations as set forth in 10 CFR Chapter I; 1
i B.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission; C.
There is reasonable assurance:
(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set.
forth in 10 CFR Chapter I; i
D.
The issuance of this license amendment will not be inimical to the common defense and security or to the health and safety of the public; E.
The issuance of this amendment is in accordance with 10 CFR Part 51 i
of the Commission's regulations and all applicable requirements have been satisfied.
e i
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,, -,..,,,,,-.y..%...,.m.,
. 2.
Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this amendment and Paragraph 2.C(2) of Facility Operating License No. NPF-15 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. 35, are hereby incorporated in the license.
};
SCE shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
This amendment is effective immediately and is to be fully implemented within 30 days of the date of issuance.
FOR THE NI! CLEAR REGULATORY COMMISSION O
Georg Knighton4-Director PWR Project Directorate No. 7 Division of PWR Licensing-B
Attachment:
Changes to the Technical Specifications Date of Issuance:
May 16, 1986 e
,me
,r---
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~
May 16, 1986 ATTACHMENT TO LICENSE AMENDMENT NO. 35 FACILITY OPERATING LICENSE NO. NPF ~5 DOCKET NO. 50-362 Replace the following page of the Appendix A Technical Specifications with the enclosed page. The revised page is identified by Amendment number and contains vertical line indicating the area of change.
Also to be replaced is the following overleaf page to the amended page.
Amendment Pages Overleaf Pages 3/4 3-28 3/4 3-27 3/4 3-29 3/4 3-30 3/4 6-1 3/4 6-2 3/4 6-19 3/4 6-20 3/4 6-21 3/4 6-22 3/4 6-23 3/4 6-24 3/4 6-25 3/4 6-26 3/4 6-27 3/4 6-28 3/4 7-10 3/4 7-9 B 3/4 6-4 B 3/4 6-3 8 3/4 6-5
~
, TABLE 3.b-5 ENGINEERED SAFhTY FFAT1)RES RESFGNSE TIMES INITI ATING SIGNAL AND FUNCTION Resp 0NSE TIME (SEC) 1.
Manual a.
SIAS NotApplica$le Safety Injection c
Control Room Isolation Not Applicable Containment Isolation (3)
Not Applicable Containment Emergency Cooling Not Applicable b.
CSAS Containment Spra Not Applicable c.
CIAS Containment Isolation Not Applicable d.
MSIS Main Steam Isolation Hot Applicable e.
RAS i
Containment Sump Recirculation Not Applicable
~
f.
CCAS Containment Emergency Cocling Hot Applicable g.
EFAS Auxiliary Feedwater Not Applicable h.
CRIS Control Room Isolation Not Applicable i.
TGIS
, Toxic Gas Isolation Not Applicable l
j.
FHIS
~
Fuel Handling Building Isolation Not Applicable
. k.
CPIS'" '
Con,tainment Purge Isolation Not Applicable N
SAN 0NOFRE-UNIT 3 3/4 3-27
Table 3.3-5 (continued) l INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) 2.
Pressurizer Pressure-Low SIAS (1) Safety Injection (a) High Pressure Safety Injection 31.2*
(b)
Low Pressure Safety Injection 41.2*
(c) Charging Pumps
~
31.2*
4 (2) Control Room Isolation Not Applicable (3) Containment Isolation (NOTE 3) 11.2* (NOTE 2)
(4) Containment Spray (Pumps) 25.6*
(5) Containment Emergency Cooling (a) CCW Pumps 31.2*
(b) CCW Valves (NOTE 4b) 23.2*
(c) Emergency Cooling Fans 21.2*
i 3.
Containment Pressure-High l
a.
SIAS (1) Safety Injection (a) High Pressure Safety Injection 41.0*
(b) Low Pressure Safety Injection 41.0*
(2) Control Room Isolation Not Applicable (3) Containment Spray (Pumps) 25.4*
(4) Containment Emergency Cooling (a) CCW Pumps 31.0*
l (b) CCW Valves-(NOTE 4b) 23.0*
(c) Emergency Cooling Fans 21.0*
b.
CIAS (1) Containment Isolation 10.9* (NOTE 2)
(2) Main Feedwater Backup Isolation 10.9 and Backup Isolation Valves (HV 4048, HV 4052, HV 1105, HV 1106, HV 4047, HV 4051) i (3) CCW Valves (Note 4a) 20.9 (4) Mainsteam Isolation Valves (HV 8204, 6.9 HV 8205)
(5) Minipurge Isolation Valves 5.9 l
4.
Containment Pressure - High-High t
CSAS l
Containment Spray 23.0*
SAN ONOFRE - UNIT 3 3/4 3-28 AMENDMENT NO. 35
Table 3.3-5 (Continued)
INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) 5.
Steam Generator Pressure - Low a.
MSIS (1) Main Steam Isolation (HV8204, HV8205) 6.9 (2) Main Feedwater Isolation (HV4048, HV4052) 10.9 (3) Steam, Blowdown and Sample Isolation e.
20.9
,, -, ~
(HV8419,HV8421)
(HV4053, HV4054, HV4057, HV4058)
(4) Auxiliary Feedwater Isolation (NOTE 7) 40.9 (HV4705, HV4713, HV4730, HV4731)
(HV4706, HV4712, HV4714, HV4715) 6.
Refueling Water Storage Tank - Low a.
RAS (1) Containment Sump Valves Open 50.7*
7.
4.16 kV Emergency Bus Undervoltage a.
LOV (loss of voltage and degraded voltage)
Figure 3.3-1 8.
Steam Generator Level - Low (and No Pressure-Low Trip) a.
EFAS (1) Auxiliary Feedwater (AC trains) 52.7*/52.7**
l (2) Auxiliary Feedwater (Steam /DC train) 42.7 (Note 6) 9.
Steam Generator Level - Low (and P - High) a.
EFAS (1) Auxiliary Feedwater (AC trains) 52.7*/52.7**
(2) Auxiliary Feedwater (Steam /DC train) 42.7 (Note 6) 10.
Control Room Ventilation Airborne Radiation a.
CRIS (1) Control Room Ventilation - Emergency Mode Not pplicable 11.
Control Room Toxic Gas (Chlorine) a.
TGIS (1) Control Room Ventilation - Isolation Mode 16 (NOTE 5)
=
12.
Control Room Toxic Gas (Ammonia) a.
TGIS (1) Control Room Ventilation - Isolation Mode 36 (NOTE 5)
SAN ON0FRE - UNIT 3 3/4 3-29 AMENDMENT NO. 35
+
o Table 3.3-5 (Continued)
INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) 13.
Control Room Toxic Gas (Butane / Propane)
TGIS Control Room Ventilation -
Isolation Mode 36 (NOTE-5) 14.
Control Room Toxic Gas (Carbon Dioxide)
TGIS Control Room Ventilation -
Isolation Mode 36 (NOTE 5) 15.
Fuel Handling Building Airborne Radiation FHIS Fuel Handling Building Post-Accident Cleanup Filter System Not Applicable 16.
Containment Airborne Radiation CPIS Containment Purge Isolation 2 (NOTE 2) 17.
Containment Area Radiation CPIS Containment Purge Isolation 2 (NOTE 2)
NOTES:
1.
Response times include movement of valves and attainment of pump or blower discharge pressure as applicable.
2.
Response time includes emergency diesel generator starting delay (applicable to AC motor operated valves other than containment purge valves), instrumentation and logic response only.
Refer to Table 3.6-1 for containment isolation valve closure times.
3.
All CIAS-Actuated valves except MSIVs and MFIVs and CCW valves 3HV-6211, l
3HV-6216, 3HV-6223 and 3HV-6236.
4a.
CCW non-critical loop isolation valves 3HV-6212, 3HV-6213, 3HV-6218 and 3HV-6219.
4b.
Containment emergency cooler CCW isolation valves 3HV-6366, 3HV-6367, 3HV-6368, 3HV-6369, 3HV-6370, 3HV-6371, 3HV-6372 and 3HV-6373 open.
5.
Response time includes instrumentation, logic, and isolation damper closure times only.
6.
The provisions of Specification 4.0.4 are not applicable for entry into MODE 3.
7.
Include HV4762 and HV4763 following implementation of DCP 195J.
Emergency diesel generator starting delay (10 seconds) and sequence loading delays for SIAS are included.
Emergency diesel generator starting delay (10 seconds) is included.
SAN ON0FRE - UNIT 3 3/4 3-30 AMENDMENT NO. 35
t 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.1.1 Primary CONTAINMENT INTEGRITY shall be maintained.
4 l
APPLICABILITY:
MODES 1, 2, 3 and 4 ACTION:
Without primary CONTAINMENT INTEGRITY, restore CONTAINMENT INTEGRITY within one hour or be in at least H0T STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD l
SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
SURVEILLANCE REQUIREMENTS 1
- 4. 6.1.1 Primary CONTAINMENT INTEGRITY shall be demonstrated:
a.
At least once per 31 days by verifying that all penetrations
- listed' in Sections A, B and C of Table 3.6-1 not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or automatic valves secured ** in their positions, except as provided 4
in Table 3.6-1 of. Specification 3.6.3.
b.
By verifying that each containment air lock is'in compliance with the requirements of Specification 3.6.1.3.
c.
After each closing of each penetration subject to Type B testing, except containment air locks, if opened following a Type A or B j
test, by leak rate testing the seal with gas at,P 55.7 psig and l
verifying that when the measured leakage rate for,these seals is added to the leakage rates determined pursuant to Specifica-4 l
tion 4.6.1.2.d for all other Type B and C penetrations, the combined leakage rate is less than 0.60 L,.
[
4 I
- Except valves, blind flanges, and automatic valves which are located inside 4
the containment and are locked, sealed or otherwise secured in the closed position.
These penetrations shall be verified closed during each COLD SHUTDOWN except that such verification need not be performed more often than 4
j once per 92 days.
- Locked, sealed or otherwise prevented from unintentional operation.
1 SAN ONOFRE-UNIT 3 3/4 6-1 AMENDMENT NO.35 i
_-,.__.-g-_-..
CONTAINMENT SYSTEMS CONTAINMENT LEAKAGE LIMITING CONDITION FOR OPERATION 3.6.1.2 Containment leakage rates shall be limited to:
a.
An overall integrated leakage rate of:
1.
Less than or equal to L 0
containmentairper24Ro,urs.10percentbyweightofthe at P,, 55.7 psig, or 2.
Less than or equal to L, 0.05 percent by weight of the containment air per 24 flours at a reduced pressure of P '
t
.27.9 psig.
b.
A combined leakage rate of less than 0.60 L for all penetrations and valvessubjecttoTypeBandCtests,when$ressurizedtoP,.
APPLICABILITY:
MODES 1, 2, 3 and 4.
ACTION:
With either (a) the measured overall integrated containment leakage rate exceeding 0.75L,allpenetr$tionsandvalvessubjecttoTypesBandCtests or 0.75 L, as applicable, or (b) with the measured combined leakage rate for exceeding 0.60 L, restore the overall integrated leakage rate to less than or a
equal to 0.75 L or less than or equal to 0.75 L, as applicable, and the combinedleakag8rateforallpenetrationsandvklvessubjecttoTypeBandC tests to less than 0.60 L prior to increasing the Reactor Coolant System temperature above 200 F. a SURVEILLANCE REQUIREMENTS 4.6.1.2 The containment leakage rates shall be demonstrated at the following test schedule and shall be determined in conformance with the criteria specified in Appendix J of 10 CFR 50 using the methods and provisions of ANSI N45.4 - 1972:
I Three Type A tests (Overall Integrated Containment Leakage Rate) a.
shall be conducted at 40 + 10 month intervals during shutdown at either P (27.9 psig) during each 10 year service $er(55.7psig)oratPThethirdtektofeachsetshallbeconducted iod.
during the shutdown for the 10 year plant inservice inspection.
i Prior to the Type A tests a visual inspection shall be conducted in l
accordance with Specification 4.6.1.6 to demonstrate the contain-ment structural integrity.
l SAN ONOFRE-UNIT 3 3/4 6-2
s CONTAINMENT SYSTEMS 3/4.6.3 CONTAINMENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.3 The containment isolation valves specified in Table 3.6-1 shall be OPERABLE with isolation times as shown in Table,3.6-1.
APPLICABILITY:
MODES 1, 2, 3 and 4.
ACTION:
1.
With one or more of the isolation valve (s) specified in Section A, B and C of Table 3.6-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration
- that is open and either:
a.
Restore the inoperable valve (s) to OPERABLE status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, or b.
Isolate each affected penetration within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> by use of at least one automatic valve secured ** in the isolation position, or one i
closed manual valve or blind flange, or c.
Be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
d.
The provisions of Specification 3.0.4 hre not applicable.
2.
With one or more of the valves specified in Section D of Table 3.6-1 inoperable, the appropriate ACTION statement (s) of those Limiting Conditions for Operation pertaining to the valve (s) or system in which it is installed shall be applicable.
SURVEILLANCE REQUIREMENTS 4.6.3.1 The isolation valves specified in Section A and B of Table 3.6-1 shall be demonstrated OPERABLE prior to returning the valve to service after mainte-nance, repair or replacement wo.k is performed on the valve or its associated actuator, control or power circuit by performance of testing pursuant to Speci-i fication 4.0.5.
Valves secured ** in their actuated position are considered OPERABLE pursuant to thi.s specification.
- Any flow path from the atmosphere or a piping system inside of containment to the atmosphere or a piping system outside of containment.
Each flow path is considered as.a separate " penetration".
- Locked, sealed or otherwise prevented from unintentional operation.
SAN ONOFRE-UNIT 3 3/4 6-19 AMENDMENT NO. 35
s CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 4.6.3.2 Each isolation valve (except check valves) specified in Section A and B of Table 3.6-1 shall be demonstrated OPERABLE during the COLD SHUTDOWN or REFUELING MODE at least once per 18 months by verifying that on an ESFAS test signal, each isolation valve actuates to its isolation position.
4.6.3.3 The isolation time of each power operated or automatic valve (except check valves) in Section A and B of Table 3.6-1 shall be determined to be within its limit when tested pursuant to Specification 4.0.5.
4.6.3.4 The manual isolation valves specified in Section C of Table 3.6-1 shall be demonstrated OPERABLE in accordance with Specifications 4.6.1.1.a and 4.6.1.2.d.
4.6.3.5 The isolation valves specified in Section D of Table 3.6-1 shall be demonstrated OPERABLE as required by Specification 4.0.5 and surveillance re-quirements associated with those Limiting Conditions for Operation pertaining to each valve or system in which it is installed.
Valves secured ** in the ESFAS actuated position are considered OPERABLE pursuant to this specification.
4 l
- Locked, sealed or otherwise prevented from unintentional operation.
SAN ON0FRE-UNIT 3 3/4 6-20 AMEN 0 MENT NO. 35
TABLE 3.6-1 CONTAINMENT ISOLATION VALVES MAXIMUM PENETRATION ISOLATION NUMBER VALVE NUMBER FUNCTION TIME (SEC)
A.
AUTOMATIC CONTAINMENT ISOLATION 1
HV-0510 Pressurizer steam space sample 40 f
1 HV-0511 Pressurizer steam space sample 40 i
2 TV-9267 Letdown line to letdown heat exchanger 40 2
HV-9205 Letdown line to letdown heat exchanger 40 i
4 HV-0508 Reactor coolant loops hot leg sample 40 4-HV-0509 Reactor coolant loops hot leg sample 40 i
i 4
HV-0517 Reactor coolant loops hot leg sample 40 6
HV-9334 Safety injection drain to RWST 40 7
HV-9217 Reactor coolant pump seal bleed off 40 l
7 HV-9218 Reactor coolant pump seal bleed off 40 i
11 HV-7911 Demineralized water to service station and i
sump pump 40 i
11 3"-236-C-675 Demineralized water to service station and i
sump pump check valve NA I 12 HV-0512 Pressurizer surge line sample 40 i
12 HV-0513 Pressurizer surge line sample 40 j
13 HV-5803 Containment sump pump discharge 40 i
13 HV-5804 Containment sump pump discharge 40 i
14 HV-5686 Fire protection 40 i
14 4"-095-C-681 Fire protection check' valve NA l 16C HV-7805 Containment air radioactivity monitor inlet 1
3 16C HV-7810 Containment air radioactivity monitor inlet 1
t 20 2"-573-C-611 Quench tank makeup check valve NA i
i 21 2"-017-C-627 Service air supply line check valve NA i
22 HV-5388 Instrument air supply line 40 i
22 1 1/2"-016-C-617 Instrument air supply line check valve 40l NA j
23A HV-5437 LP N to containment 2
23A 3/4"-002-C-611 LP N to containment check valve 26 HV-7512 Reactor coolant drain tank pump discharge 40l 2
NA l
26 HV-7513 Reactor coolant drain tank pump discharge 40 1
27C HV-7806 Containment air radioactivity monitor outlet 1
27C HV-7811 Containment air radioactivity monitor cutlet 1
30A HV-7802 Containment air radioactivity monitor outlet 1
30A HV-7803 Containment air radioactivity monitor outlet 1
i 308 HV-7801 Containment air radioactivity monitor outlet 1
30B HV-7800 Containment air radioactivity monitor outlet 1
j 308 HV-7816 Containment air radioactivity monitor outlet 1
)
30C HV-0516 Quench tank and drain tank gas sample 40 i
30C HV-0514 Quench tank and drain tank gas sample 40 30C HV-0515 Quench tank and drain tank gas sample 40 42 HV-6211 42 HV-6223 Component cooling water inlet 40 Component cooling water inlet 40 l
43 HV-6236 Component cooling water outlet 40 4
4
}
l SAN ONOFRE-UNIT 3 3/4 6-21 AMEN 0 MENT N0. 35 i
..x
TABLE 3.6-1 (Continued)
CONTAINMENT ISOLATION VALVES F
MAXIMUM PENETRATION ISOLATION NUMBER VALVE NUMBER FUNCTION TIME (SEC)
A.
AUTOMATIC CONTAINMENT ISOLATION (Cont.)
43 HV-6216 Component cooling water outlet 40 45 HV-9900 Containment normal A/C chilled water inlet 40 l
45 HV-9920 Containment normal A/C chilled water inlet 40 46 HV-9971 Containment normal A/C chilled water outlet 40 i
46 HV-9921 Containment normal A/C chilled water outlet 40 47 HV-7258 Containment waste gas vent header 40 47 HV-7259 Containnent waste gas vent header.
40
~
4 i
68 2"-129-A-554 Charging line to auxiliary spray check valve NA l l
77 HV-5434 Nitrogen supply to safety injection tanks 40 j
77 2"-108-C-627 Nitrogen supply to safety injection tanks check valve NA I i
B.
CONTAINMENT PURGE (CPIS)
)
l 18 HV-9949**
Containment purge inlet (normal) 12 i
18 HV-9948**
Containment purge inlet (normal) 12 18 HV-9821 Containment mini purge inlet 5
18 HV-9823 Containment mini purge inlet 5
i 19 HV-9950**
Containment purge outlet (normal) 12 j
19 HV-9951**
Containment purge outlet (normal) 12 i
19 HV-9824 Containment mini purge outlet 5
]
Containment mini purge outlet 5
19 HV-9825 C.
MANUAL
- 6 2"-099-C-334 Safety injection drain to RWST NA 9
HV-9337M Shutdown cooling to LPSI pumps NA j.
9 HV-9377M Shutdown cooling to LPSI pumps NA 9
HV-9336M Shutdown cooling to LPSI pumps NA l
9 HV-9379M Shutdown cooling to LPSI pumps NA i
10C 3/4"-038-C-396 Integrated leak rate test pressure sensor NA 10C 3/4"-039-C-396 Integrated leak rate test pressure sensor NA i
16A HV-0500 Post LOCA hydrogen monitor NA 16A HV-0501 Post LOCA hydrogen monitor NA l
16B HV-0502 Post LOCA hydrogen monitor NA 1
16B HV-0503 Post LOCA hydrogen monitor NA 20 2"-321-C-376 Quench tank makeup NA l l
O Manual valves may be opened on an intermittent basis under administrgt.ive control.
00 Power to the valve removed in accordance with Specification 3.6.1.7.
i
- Not subject to Type C leakage tests.
{
@ Shutdown cooling valves may be opened in MODE 4.
f SAN ONOFRE-UNIT 3 3/4 6-22 AMEN 0 MENT NO. 35
- -. -.,,,. -.- -,,.~ - - n -....,.,
.., -. -.. ~,. ~, - -. -. - ~.. - -, - - - -,.. - -..,,.. -,,.
s TABLE 3.6-1 (Continued)
CONTAINMENT ISOLATION VALVES MAXIMUM PENETRATION ISOLATION NUMBER VALVE NUMBER FUNCTION TIME (SEC)
C.
MANUAL * (Cont.)
21 2"-055-C-387 Service air supply line NA 25 10"-100-C-212 Refueling canal fill and drain NA 1 25 10"-101-C-212 Refueling canal fill and drain NA 31 HV-9946 Containment hydrogen purge inlet NA 31 HCV-9945 Containment hydrogen purge inlet NA 1 68 2"-130-C-334 Charging line to auxiliary spray NA 70 2"-037-C-387 Auxiliary steam inlet to utility stations NA 70 2"-038-C-387 Auxiliary steam inlet to utility stations NA 74 HV-9917 Containment hydrogen purge outlet NA 74 HCV-9918 Containment hydrogen purge outlet NA D.
OTHER***
3 3"-018-A-551#
High pressure safety injection NA 3
HV-9323#
High pressure safety injection NA 3
HV-9324#
High pressure safety injection NA 5
3"-019-A-551#
High pressure safety injection NA 5
HV-9326#
High pressure safety injection NA 5
HV-9327#
High pressure safety injection NA 8
2"-122-C-554 Charging line to regenerative heat exchanger NA 8
HV-9200 Charging line to regenerative heat exchanger NA 10A HV-0352A#
Containment pressure detectors NA 17 HV-4058#*
Steam generator secondary coolant sample NA 27A HV-03520#
Containment pressure detectors NA 32 HV-8202#
Mainsteam isolation bypass NA 33 HV-8203#
Mainsteam isolation bypass NA 36 HV-4054#*
Steam generator blowdown NA 37 HV-4053#*
Steam generator blowdown NA 39 3"-020-A-551#
High pressure safety injection NA 39 HV-9329#
High pressure safety injection NA 39 HV-9330#
High pressure safety injection NA 40A HV-0352B#
Containment pressure detectors NA 41 3"-021-A-551#
High pressure safety injection NA 41 HV-9332#
High pressure safety injection NA Manual valves may be opened on an intermittent basis under administrative control.
Not subject to Type C leakage tests.
SAN ONOFRE-UNIT 3 3/4 6-23 AMENDMENT NO. 35
TABLE 3.6-1 (Continued)
CONTAINMENT ISOLATION VALVES MAXIMUM PENETRATION ISOLATION NUMBER NALVE NUMBER FUNCTION TIME (SEC)
D.
OTHER*** (Cont.)
41 HV-9333#
High pressure safety injection NA 44 HV-4057#*
Steam generator secondary coolant sample NA 48 8"-072-A-552#
Low pressure safety injection NA 48 HV-9322#
Low pressure safety injection NA 49 8"-073-A-552#
Low pressure safety injection NA 49 HV-9325#
Low pressure safety injection NA 50 8"-074-A-552#
Low pressure safety injection NA 50 HV-9328#
Low pressure safety injection NA 51 8"-075-A-552#
Low pressure safety injection NA 51 HV-9331#
Low pressure safety injection NA 52 8"-004-C-406 Containment spray inlet NA 52 HV-9367 Containment spray inlet NA 53 Q"-006-C-406 Containment spray inlet NA 53 HV-9368 Containment spray inlet NA 54 HV-9304#
Containment emergency' sump recirculation NA 54 HV-9302#
Containment emergency sump recirculation NA 55 HV-9305#
Containment emergency sump recirculation NA 55 HV-9303#
Containment emergency sump recirculation NA 56 HV-6366 Containment emergency A/C cooling water inlet NA 57 HV-6372 Containment emergency A/C cooling water inlet NA 58 HV-6368 Containment emergency A/C cooling water inlet NA 59 HV-6370 Containment emergency A/C cooling water inlet NA 60 HV-6369 Containment emergency A/C cooling water outlet NA 61 HV-6371 Containment emergency A/C cooling water outlet NA 62 HV-6367 Containment emergency A/C cooling water outlet NA 63 HV-6373 Containment emergency A/C cooling water outlet NA 67 3"-157-A-550 Hot leg injection NA 67 HV-9434 Hot leg injection NA 71 3"-158-A-550 Hot leg injection NA 71 HV-9420 Hot leg injection NA 73A HV-0352C#
Containment pressure detectors NA-c 0 Manual valves may be opened on an intermittent basis under administrative control.
000 Valves secured in the ESFAS actuated position are considered OPERABLE pursuant to l
this specification.
Not subject to Type C leakage tests.
P SAN ON0FRE-UNIT 3 3/4 6-24 AMENDMENT NO. 35
a a
d DELETED INTENTIONALLY 5
e 1
l
?-
1 I
i l
SAN ONOFRE-UNIT 3 3/4 6-25 AMENDMENT NO. 35
O e
f l
DELETED' INTENTIONALLY f
e 4
I i
1 I,
e.
h 1
~
SAN ONOFRE-UNIT 3 3/4 6-26 AMEN 0 MENT NO. 35 s
f 3
s CONTAINMENT SYSTEMS 3/4.6.4 COMBUSTIBLE GAS CONTROL HYDR 0 GEN MONITORS LIMITING CONDITION FOR OPERATION 3.6.4.1 Two independent containment hydrogen monitors shall be OPERABLE.
APPLICABILITY:
MODES 1 and 2.
ACTION:
1 a.
With one hydrogen monitor inoperable, restore the inoperable monitor to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
b.
With two hydrogen monitors inoperable, restore at least one hydrogen monitor to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
c.
With one hydrogen monitor inoperable, the provisions of Specifica-tion 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.6.4.1 Each hydrogen monitor shall be demonstrated OPERABLE by:
The performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days, a.
and b.
At least once per 92 days on a STAGGERED TEST BASIS, by performing a CHANNEL CALIBRATION using the following sample gases:
i)
Nitrogen, and ii) Four volume percent hydrogen, balance nitrogen.
SAN ON0FRE-UNIT 3 3/4 6-27 AMENDMENT NO. 35
6 s
CONTAINMENT SYSTEMS ELECTRIC HYDROGEN RECOMBINERS LIMITING C0NDITION FOR OPERATION 3.6.4.2 Two independent centsinnent hydrogen recombiner systems shall be OPERABLE.
APPLICABILITY:
MODES 1 and 2.
ACTION:
With one hydrogen recombiner system inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.6.4.2 Each hydrogen recombiner system shall be demonstrated OPERABLE:
a.
At least once per 6 months by verifying, daring a recombiner system functional test, that the minimum heater sheath temperature increases to greater than or equal to 700*F within 90 minutes.
Upon-reathing 700*F, increase the power setting to maximum power for 2 minutes and verify that the power meter reads greater than or equal to 60 kw.
b.
At least once per 18 months 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 abnormel conditions within the recombiner enc 1csure l
(i.e., loose wiring or structurel connections, deposits of foreign materials, etc.), and i
3.
Verifying the integrity of the heater electrical circuits by performing a resistance to ground test following the above required function'al test.
The resistance to ground for any
]
heater phase shall be greater than or equal to 10,000 ohms, SAN ONOFRE-UNIT 3 3/4 6-28
TABLE 4.7-1 SECONDARY COOLANT SYSTEM SPECIFIC ACTIVITY SAMPLE AND ANALYSIS PROGRAM TYPE OF MEASUREMENT
wSAMPLE-AND ANALYSIS AND ANALYSIS FREQUENCY 1.
Gross Activity Determination At least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 2
. Isotopic Analysis for DOSE a) 1 per 31 days, whenever the EQUIVALENT I-131 Concentration gross activity determination indicates iodine concentrations greater than ' 5 of the allowable limit.
b) 1 per 6 months, whenever the gross activity determination indicates iodine concentrations below 10% of the allowable limit.
1
.6 m
G F
SAN ON0FRE-UNIT 3 3/4 7-9
s PLANT SYSTEMS MAIN STEAM LINE ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.7.1.5 Each main stea~m line icolation valve shall be OPERABLE.
APPLICABILITY:
MODES 1, 2 and 3.
ACTION:
H0DE 1 With one main steam line isolation valve inoperable but open, POWER OPERATION may continue provided the inoperable valve is restored to OPERABLE status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />; otherwise, reduce power to less than or equal to 5 percent RATED THERMAL POWER
'within the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
MODES 2 With one main Steam line isolation valve inoperable, and 3 subsequent operation in MODES 2 or 3 may proceed provided:
a.
The isolation valve is maintained closed.
b.
The provisions of Specification 3.0.4 are not applicable.
Otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.7.1.5 Each main steam line isolation valve shall be demonstrated OPERABLE by verifying full closure within 6.0 seconds when tested pursuant to Specification 4.0.5.
i SAN ONOFRE-UNIT 3 3/4 7-10 AMENDMENT NO. 35
- - l
s 4
l CONTAINMENT SYSTEMS
(
BASES 1
3/4.6.1.7 CONTAINMENT VENTILATION SYSTEM s
j The 42-inch containment purge supply and exhaust isolation valves are i
required to be closed during plant operation since these valves have not been demonstrated capable of clo. sing during a LOCA or steam line break accident.
Maintaining these valves closed during plant operations ensures that excessive.
quantities of radioactive materials will not be released via the containment i
purge system. To provide assurance that the 42-inch valves cannot be inadvert-j ently opened, they are sealed closed in accordance with Standard Review Plan 6.2.4 i
which includes mechanical devices to seal or lock the valve closed or prevent power-from being supplied to the valve operator.
l The use of the containment purge lines is restricted to the 8-inch purge 1
supply and exhaust isolation valves since, unlike the 42-inch valves, the 8-inch valves will close during a LOCA or steam line break accident and there-fore the site boundary dose guidelines of 10 CFR Part 100 would not be exceeded j
in the event of an accident during purging operations.
The design of the 8-inch purge supply and exhaust isolation valves meets the requirements of j
j Branch Technical Position CSB 6-4, " Containment Purging During Normal Plant Operations."
i Leakage integrity tests with a maximum allowable leakage rate for purge supply i
and exhaust-isolation valves will provide early indication of resilient material j l seal degradation and will allow the opportunity for repair before gross leakage j
failure develops.
The 0.60 L leakage limit shall not be exceeded when the leakage rates determined by tRe leakage integrity tests of these valves are added to the previously determined total for all valves and penetrations subject to Type B and C tests.
3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS i
3/4.6.2.1 CONTAINMENT SPRAY SYSTEM The OPERABILITY of the containment spray system ensures that containment j
depressurization and cooling capability will be available in the event of a l
LOCA.
The pressure reduction and resultant lower containment leakage rate are consistent with the assumptions used in the accident analyses.
~
j l
The containment spray system and the containment cooling system are i
redundant to each other in providing post accident cooling of the containment l
atmosphere.
However, the containment spray system also provides a mechanism
)
for removing iodine from the containment atmosphere and therefore the time j
requirements for restoring an inoperable spray system to OPERABLE status have j
been maintained consistent with that assigned other inoperable ESF equipment.
1 l
I I
I i
SAN ONOFRE-UNIT 3 B 3/4 6-3 u.
s CONTAINMENT SYSTEMS BASES l
i 3/4.6.2.2 IODINE REMOVAL SYSTEM 3
The OPERABILITY of the iodine removal system ensures that sufficient Na0H is added to the containment spray in the event of a LOCA.
The limits on Na0H volume and concentration ensure that the solution recirculated within contain-ment after a LOCA has a pH value vetween 8.0 and 10.0 at the end of the Na0H injection period.
This pH band minimizes the evolution of iodine and minimizes the effect of chloride and caustic stress corrosion mechanical systems and com-ponents.
The contained water volume limit includes an allowance for water not usable because of tank discharge line location or other physical characteristics.
These assumptions are consistent with the iodine removal efficiency assumed in the accident analyses.
The 5 year Surveillance testing is intended to verify that no crystalliza-tion of the Na0H or other obstruction has occurred in the piping from the spray additive tank to the suction of the containment spray pumps.
3/4.6.2.3 CONTAINMENT COOLING SYSTEM The OPERABILITY Of the containment cooling system ensures that 1) the con-tainment air temperature will be maintained within limits during normal opera-tion, and 2) adequate heat removal capacity is available when operated in con-junction with the containment spray systems during post-LOCA conditions.
i The containment cooling system and the containment spray system are redun-l dant to each other in providing post-accident cooling of the containment atmos-t phere.
As a result of this redundancy in cooling capability, the allowable out-of-service time requirements for the containment cooling system have been appropriately adjusted.
However, the allowable out-of-service time requirements i
for the containment spray system have been maintained consistent with that I
assigned other inoperable ESF equipment since the containment spray system also l
provides a mechanism for removing iodine from the containment atmosphere.
3/4.6.3 CONTAINMENT ISOLATION VALVES i
The OPERABILITY of the containment isolation valves ensures that the contain-q ment atmosphere will be isolated from the outside environment in the event of a release of radioactive material to the containment atmosphere and is consis-tent with the requirements of GDC 54 through 57 of Appendix A to 10 CFR 50.
Containment isolation within the time limits specified for those power operated isolation valves designed to close automatically upon a CIAS signal ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a LOCA.
Such valves are listed in Sections A and B of Table 3.6-1 and Surveillance requirements to verify-OPERABILITY of these valves are explicitly stated in 4.6.3.1 thru 4.6.3.3.
Check valves located inside containment are considered OPERABLE provided their leak rate is within limits when tested pursuant to 10 CFR 50 Appendix J.
Section C of Table 3.6-1 contains a listing of manual valves that are normally closed and assumed to be closed under design basis accident conditions,'but which may be opened intermittently for service, maintenance or test during
~
normal operation provided adequate administrative controls are implemented to ensure operator action is taken to close such valves in the event of an accident.
g
+
t l
SAN ONOFRE - UNIT 3 B 3/4 6-4 AMEN 0 MENT NO.
35
,g.-,
y
%g
...e.
eem *
.--W~1---
- WT" ' ' " " " * * * * * ' --"'T'#
Y'
~'
s CONTAINMENT SYSTEMS BASES 3/4.6.3 CONTAINMENT ISOLATION VALVES (Continued)
All valves in Section A, B or C are considered OPERABLE for containment isola-tion purpose if they aie indeed locked, sealed or'ptheyw,ise secured in the closed position and leakage through the affected flow path is shown to be within limits when tested pursuant to 10 CFR 50 Appendix J.
Section D of Table 3.6-1 contains a listing of valves which operate automati-cally on an ESFAS signal to prevent or mitigate the consequences of the design basis accident.
Surveillance requirement 4.6.1.1.a is not applicable to such valves.
The OPERABILITY of such valves is determined by ESFAS response time testing of Specification 3/4.3.2.
Valves in Section D that are locked, sealed or otherwise secured in their ESFAS actuated position will permit performance of their safety function and are, therefore, considered OPERABLE pursuant to i
this specification.
l 3/4.6.4 COMBUSTIBLE GAS CONTROL The OPERABILITY of the equipment and systems required for the detection and control of hydrogen gas ensures that this equipment will be available to maintain the hydrogen concentration within containment below its flammable limit during post-LOCA conditions.
Either recombiner unit is capable of controlling the expected hydrogen generation associated with 1) zirconium-water reactions, 2) radiolytic decomposition of water and 3) corrosion of metals within containment.
These hydrogen control systems are consistent with the recommendations of Regulatory Guide 1.7, " Control of Combustible Gas Concentrations in Containment Following a LOCA", March 1971.
The containment dome air circulators are provided to ensure adeq'uate mixing of the containment atmosphere following a LOCA.
The mixing action of the containment dome air circulators combined with the containment spray system and the containment emergency fan coolers will prevent localized accumulations of hydrogen from exceeding the flammable limit.
O SAN ON0FRE - UNIT 3 B 3/4 6-5 AMENDMENT N0. 35
,