ML20210M804
| ML20210M804 | |
| Person / Time | |
|---|---|
| Site: | San Onofre  |
| Issue date: | 09/09/1986 |
| From: | Rood H Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20210M809 | List: |
| References | |
| TAC-54732, TAC-59881, TAC-59882, NUDOCS 8610060012 | |
| Download: ML20210M804 (16) | |
Text
[o UNITED STATES g
[
g NUCLEAR REGULATORY COMMISSION G
j WASHINGTON, D. C. 20555
,, \\...../
SOUTHERN CALIFORNIA EDISON COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RIVERSIDE, CALIFORNIA THE CITY OF ANAHEIM, CALIFORNIA DOCKET NO. 50-361 SAN ONOFRE NUCLEAR GENERATING STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 55 License No. NPF-10 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 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 April 2, 1984 and July 1, 1985, comply with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Comission's regulations as set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Comission; C.
There is reasonable assurance:
(1)thattheactivitiesauthorized 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 Comission's regulations set forth in 10 CFR Chapter 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 of the Comission's regulations and all applicable requirements have been satisfied.
Su288Ei8888))p P
. 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. 55, are hereby incorporated in the license.
SCE shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
The change in Technical Specifications is to become effective within 30 days of issuance of the amendment.
In the period between issuance of the amendment and the effective date of the new Technical Specifications, the licensees shall adhere to the Technical Specifications existing at the time. The period of time during change over shall be minimized.
4.
ThislicenseamendmentiseffectIveasofthedateofitsissuance.
FOR THE NUCLEAR REGULATORY COMMISSION k
Harry Rood, Senior Project Manager PWR Project Directorate No. 7 Division of PWR Licensing-B
Attachment:
Changes to the Technical Specifications Date of Issuance: September 9, 1986
September 9, 1986 ATTACHMENT TO LICENSE AMENDMENT NO. 55 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 contain vertical lines indicating the area of change. Also to be replaced are the following overleaf pages to the amended pages.
Amendment Pages Overleaf Pages 3/4 3-29 3/4 3-30 3/4 5-5 3/4 5-6 i
l
Table 3.3-5 (Conti(9;;d)
INITIATING SIGNAL AND FUNCTION RESPONSE TIME (SEC) 5.
Steam Generator Pressure - Low MSIS (1) Main Steam Isolation (HV8204, HV8205) 6.9 (2) Main Feedwater Isolation (HV4048, HV4052) 10.9 (3) Steam,BlowdownandSample.Jsolation 20.9 (HV8419,HV8421)
(HV4053, HV4054, HV4057, H';$058)
(4) Auxiliary Feedwater Isolatton (NOTE 7) 40.9 (HV4705,HVi713,HV4730,H/4731)
(HV4706, HV4724. iiV4714, H%'r71;3) 6.
Refueling Water Storage Tank - Low RAS (1) Containment Sump Valves Open 50.7*
(2) ECCS Miniflow Isolation Valves Close 50.7* (Note 8) l 7.
4.16 kv Emergency Bus Undervoltage LOV (loss of voltage and degraded voltage)
Figure 3.3-1 8.
Steam Generator Level - Low (and No Pressure-Low Trip)
EFAS (1) Auxiliary Feedwater (AC trains) 52.7*/52.7**
(2) Auxiliary Feedwater (Steam /DC train) 42.7 (NOTE 6) 9.
Steam Generator Level - Low (and AP - High)
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 CRIS (1) Control Room Ventilation - Emergency Mode Not Applicable 11.
Control Room Toxic Gas (Chlorine)
TGIS (1) Control Room Ventilation - Isolation Mode 16 (NOTE 5) 12.
Control Room Toxic Gas (Ammonia)
TGIS Control Room Ventilation - Isolation Mode 36 (NOTE 5) l l
l SAN ONOFRE - UNIT 2 3/4 3-29 AMENDMENT NO. 55
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.
FLel Handlina Building Airborne Radiation FHIS Fuel Handling Building Post-Accident Cleanup Filter System Not Applicable 15.
Containment Airborne Radiation CPIS Containment Purge Isolation 2 (NOTE 2) 16.
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 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 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.
8 Prior to completion of DCP 6234, valve closure is manually initiated.
Following completion of DCP 6234, valves are to close automatically on a RAS coincident with a high-high containment sump signal.
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 AMENDMENT NO. 55 k
EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 2.
A visual inspection of the containment sump and verifying that the subsystem suction inlets are not restricted by debris and that the sump components (trash racks, screens, etc.) show no evidence of structural distress or abnormal corrosion.
e.
At least once per 18 months, during shutdown, by:
1.
Verifying that each automatic valve in the flow path actuates to its correct position on SIAS and RAS test signals.
2.
Verifying that each of the following pumps start automatically upon receipt of a Safety Injection Actuation Test Signal:
a.
High-Pressure Safety Injection pump.
b.
Low-Pressure Safety Injection pump.
c.
Charging pump.
3.
Verifying that on a Recirculation Actuation Test Signal, the containment sump isolation valves open; and that on a RAS test signal coincident with a high-high containment sump test signal, all the recirculation valves to the refueling water tank close.
f.
By verifying that each of the following pumps develops the indicated developed head and/or flow rate when tested pursuant to Specification 4.0.5:
1.
High-Pressure Safety Injection pumps developed head, at an indi-cated flow rate of 650 gpm, greater than or equal to 2142 feet for P017, 2101 feet for P018 and 2103 for P019 (see NOTE 1).
2.
Low-Pressure Safety Injection pump developed head greater than or equal to 406.1 feet.
3.
Charging pump flow rate greater than or equal to 40 gpm.
g.
By performing a flow balance test, during shutdown, following comple-tion of modifications to the ECCS subsystems that alter the subsystem I
flow characteristics and verifying the following flow rates:
l 1.
For High-Pressure Safety Injection pump cold leg injection with a single pump running:
a.
The sum of the injection lines flow rates, excluding the highest flow rate, is greater than or equal to 657 gpm for P017 running, 667 gpm for P018 running and 672 gpm for P019 running, and b.
The total pump flow rate is greater than or equal to 900 gpm for P017 running, 913 gpm for P018 running l
and 918 gpm for P019 running.
SAN ONOFRE-UNIT 2 3/4 5-5 AMENDMENT NO. 55
EltERGENCY CORE COOLING SYSTEMS
(
SURVEILLANCE REQUIREMENTS (Continued) 2.
For a single High-Pressure Safety Injection pump hot / cold leg injection.
a.
Th.e sum of the cold leg injection flow rates is greater than or equal to 385 gps, and i
b.
The hot leg injection flow rate is greater than or equal to 385 gpm.
The combined total hot / cold legs injection flow rate is c.
greater than oc equal to 896 gpm.
3.
For the Low-Pressure Safety Injection" pump with a single pump running:
a.
The flow through each injection leg shall be greater than or equal to 3000 gpm when tested individually and corrected to the same pump suction source and leg back pressure i
conditions.
The difference between high and low flow legs shall be less than or equal to 100 gpm.
{
b.
The total ECCS flow through 2 cold leg injection lines shall be greater than or equal to 4450 gpm when corrected for elevation head.
l 6
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4 k
SAN ONOFRE-UNIT 2 3/4 5-6
,(j;3 5sog'g UNITED STATES g
g NUCLEAR REGULATORY COMMISSION c
-l WASHINGTON, D. C. 20555
\\..../
SOUTHERN CALIFORNIA EDISON COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RIVERSIDE, CALIFORNIA THE CITY OF ANAHEIM, CALIFORNIA DOCKET NO. 50-362 SAN ONOFRE NUCLEAR GENERATING STATION, UNIT 3 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 44 License No. NPF-15 1.
The Nuclear Regulatory Commission (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 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 April 2, 1984 and July 1, 1985, comply with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Comission's regulations as set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Comission; 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 conducted in compliance with the Comission's regulations set forth in 10 CFR Chapter I; D.
The issuance of this license amendment will not be inimical to the comon 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 of the Comission's regulations and all applicable requirements have been satisfied.
4
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. 44, are hereby incorporated in the license.
SCE shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
The change in Technical Specifications is to become effective within 30 days of issuance of the amendment.
In the period between issuance of the amendment and the effective date of the new Technical Specifications, the licensees shall adhere to the Technical Specifications existing at the time. The period of time during change over shall be minimized.
4.
This license amendment is effective as of the date of its issuance.
FOR THE NUCLEAR REGULATORY COMMISSION Harry Rood, Senior Project Manager PWR Project Directorate No. 7 Division of PWR Licensing-B
Attachment:
Changes to the Technical Specifications Date of Issuance: September 9, 1986 i
i
September 9, 1986 ATTACHMENT TO LICENSE AMENDMENT NO. 44 FACILITY OPERATING LICENSE NO. NPF-15 DOCKET NO. 50-362 Replace the following pages of the Appendix A Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change. Also to be replaced are the following overleaf pages to the amended pages.
Amendment Page Overleaf Page 3/4 3-29 3/4 3-30 3/4 5-4 3/4 5-3 3/4 5-5 3/4 5-6
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 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*
(2) ECCS Miniflow Isolation Valves close 50.7* (Note 8) 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**
(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 Applicable 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 ONOFRE - UNIT 3 3/4 3-29 AMENDMENT NO. 44
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.
Fuel Handling Building Airborne Radiation FHIS Fuel Handling Building Post-Accident Cleanup Filter System Not Applicable 15.
Containment Airborne Radiation CPIS Containment Purge Isolation 2 (NOTE 2) 16.
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, 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.
8.
Prior to completion of DCP 6234, valve closure is manually initiated.
Following completion of DCP 6234, valves are to close automatically on a RAS coincident with a high-high containment sump signal.
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 ONOFRE - UNIT 3 3/4 3-30 AMENDMENT NO. 44
EMERGENCY CORE COOLING SYSTEMS 3/4.5.2 ECCS SUBSYSTEMS - T GREATER THAN OR EQUAL TO 350*F LIMITING CONDITION FOR OPERATION 3.5.2 Two independent Emergency Core Cooling System (ECCS) subsystems shall be OPERABLE with each subsystem comprised of:
a.
One OPERABLE high pressure safety injection pump, b.
One OPERABLE low pressure safety injection pump, and c.
One OPERABLE charging pump capable of taking suction from either the boric acid makeup tank or.the refueling water storage tank, d.
An independent CPERABLE flow path capable of taking suction from the refueling water tank on a Safety Injection Actuation Signal and automatically transferring suction to the containment sump on a Recirculation Actuation Signal.
APPLICABILITY: MODES 1, 2 and 3*.
ACTION:
a.
With one ECCS subsystem inoperable, restore the inoperable subsystem 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 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 />.
b.
In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 90 days describing the circumstances of the actuation and the total accumu-lated actuation cycles to date. The current value of the usage factor for each affected safety injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.
"With pressurizer pressure greater than or equal to 400 psia.
(
f SAN ONOFRE-UNIT 3 3/4 5-3
EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS 4.5.2 Each ECCS subsystem shall be demonstrated OPERABLE:
a.
At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by verifying that the following valves are in the indicated positions with power to the valve operators removed:
Valve Number Valve Function Valve Position a.
HV9353 SDC Warmup CLOSED b.
HV9359 SDC Warmup CLOSED c.
HV8150 SDC(HX) Isolation CLOSED d.
HV8151 SDC(HX) Isolation CLOSED e.
HV8152 SDC(HX) Isolation CLOSED f.
HV8153 SDC(HX) Isolation CLOSED g.
HV0396 SDC Bypass Flow Control CLOSED h.
HV8161 SDC(HX) Bypass Flow OPEN l
Isolation i.
Deleted j.
Deleted k.
HV9420 Hot Leg Injection CLOSED Isolation 1.
HV9434 Hot Leg Injection CLOSED Isolation m.
HV8160 SDC Bypass Flow OPEN l
Control n.
HV8162 LPSI Miniflow OPEN Isolation o.
HV8163 LPSI Miniflow OPEN Isolation b.
At least once per 31 days by:
1.
Verifying that the ECCS piping is full of water by venting the ECCS pump casings and accessible discharge piping high points, and 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 the correct position.
c.
By a visual inspection which verifies that no loose debris (rags, trash, clothing, etc.) is present in the containment which could be transported to the containment sump and cause restriction of the pump suctions during LOCA conditions.
This visual inspection shall be performed:
1.
For all accessible areas of the containment prior to establishing i
CONTAINMENT INTEGRITY, and 2.
Of the areas affected within containment at the completion of containment entry when CONTAINMENT INTEGRITY is established.
d.
At least once per 18 months by:
1.
Verifying automatic isolation of the shutdown cooling system from the Reactor Coolant System when RCS pressure is simulated greater than or equal to 715 psia, and that the interlocks prevent opening the shutdown cooling system isolation valves when simulated RCS pressure is greater than or equal to 376 psia.
SAN ONOFRE - UNIT 3 3/4 5-4 AMENDMENT NO. 44
r EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 2.
A visual inspection of the containment sump and verifying that the subsystem suction inlets are not restricted by debris and that the sump components (trash racks, screens, etc.) show no evicence of structural distress or abnormal corrosion.
e.
At least once per 18 months, during shutdown, by:
1.
Verifying that each automatic valve in the flow path actuates to its correct position on SIAS and RAS test signals.
2.
Verifying that each of the following pumps start automatically upon receipt of a Safety Injection Actuation Test Signal:
a.
High-Pressure Safety Injection pump.
b.
Low-Pressure Safety Injection pump.
c.
Charging pump.
3.
Verifying that on a Recirculation Actuation Test Signal, the containment sump isolation valves open; and that on a RAS test signal coincident with a high-high containment sump test signal, all the recirculation valves to the refueling water tank close, f.
By verifying that each of the following pumps develops the indicated developed head and/or flow rate when tested pursuant to Specification 4.0.5:
1.
High-Pressure Safety Injection pumps developed head, at an indicated flow rate of 650 gpm, greater than or equal to 2093 feet for P017, 2132 feet for P018 and 2099 for P019 (see NOTE 1).
2.
Low-Pressure Safety Injection pump developed head greater than or equal to 396 feet at miniflow.
3.
Charging pump flow rate greater than or equal to 40 gpm.
g.
By performing a flow balance test, during shutdown, following completion of modifications to the ECCS subsystems that alter the subsystem flow characteristics and verifying the following flow rates:
1.
For High-Pressure Safety Injection pump cold leg injection with a single pump running:
a.
The sum of the injection lines flow rates, excluding the highest flow rate, is greater than or equal to 647 gpm for P017 running, 656 gpm for P018 running, and 661 gpm for P019 running, and b.
The total pump flow rate is greater than or equal to 882 gpm for P017 running, 894 gpm for P018 running, and 901 gpm for P019 running.
SAN ONOFRE - UNIT 3 3/4 5-5 AMENDMENT NO. 44
EMERGENCY CORE COOLING SYSTEMS
(
SURVEILLANCE REQUIREMENTS (Continued) 2.
For a single High-Pressure Safety Injection pump ho'/ cold leg t
injection.
a.
The sum of the cold leg injection flow rates is greater than or equal to 385 gpa, and b.
The hot leg injection flow rate is greater than or equal to 385 gpm.
The combined total hot / cold legs in'jection flow rate is c.
greater than or. eg0a1 to 896 gpm.
3.
For the Low-Pressure Safety Injection pump wi,th a single pump running:
a.
The flow through each injection leg shall be greater than or equal to 3000 gpm when tested individually and corrected to the same pump suction source and leg back pressure conditions.
The difference between high and low flow legs shall be less than or equal to 100 gpm.
b.
The total ECCS flow through two cold leg injection lines shall be greater than or equal to 4450 gpm when corrected for elevation head.
I SAN ONOFRE-UNIT 3 3/4 5-6
-