ML20198S546
| ML20198S546 | |
| Person / Time | |
|---|---|
| Site: | San Onofre  |
| Issue date: | 12/22/1998 |
| From: | NRC (Affiliation Not Assigned) |
| To: | |
| Shared Package | |
| ML20198S551 | List: |
| References | |
| NUDOCS 9901110356 | |
| Download: ML20198S546 (30) | |
Text
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'4 UNITED STATE 8
(
)
NUCLEAR REGULATORY COMMISSION t
WASHINGTON, D.C. 30506-0001 l
o,
'% * * * * * /g 1
l SOUTHERN CALIFORNIA EDISON COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RIVERSIDE. CALIFORNIA THE CIW OF ANAHEIM. CALIFORNIA DOCKET NO. 50-361 SAN ONOFRE NUCLEAR GENERATING STATION. UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.147 License No. NPF-10 1.
The Nuclear Regulatory Commission (the Commission) has found that:
A.
The application for amendment by Southem Califorrila Edison Company, et al.
(SCE or the licensee) dated June 30,1997, complies with the standards and requirements of the Atomic Energy Act of 1954, as amendec, (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, the provisions of the Act, and 'he rules and 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; D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
l 9901110356 981222 i
PDR ADOCK 05000361 p
PDR I
!(' l 2.
According!y, the license is amended by changes to the Technical Specifications as l
Indicated in the attachment to this license amendment and paragraph 2.C(2) of Facility l
Operating License No. NPF-10 is hereby amended to read as follows:
2.
Technical Specifications l
The Technical Specifications contained in Appendix A and the Environmental l
Protection Plan contained in Appendix B, as revised through Amendment No.
147
, are hereby incorporated in the license. Southem Califomia Edison Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
Also, the license is amended by deleting paragraph 2.C.(19)b," Shift Manning."
4.
This license amendment is effective as of the date of its issuance and is to be implemented within 30 days of its date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION l
u).
J l
ames 'N. Clifford, Senior Project Manager l
Project Directorate IV-2 Division of Reactor Projects lil'lV Office of Nuclear Reactor Regulation i
Attachments: 1. Changes to the Technical Specifications
- 2. Pages 7 and 8 of Facility Operating License No. NPF-10 Date of issuance:
December 22, 1998 I
l 1
I
ATTACHMENTTO LICENSE AMENDMENT l
AMENDMENT NO.147 TO FACILITY OPERATING LICENSE NO. NPF-10 l
DOCKET NO. 50-361 i
l Revise Appendix A Technical Specifications by removing the pages identified below and inserting the enclosed pages. The revised pages are identified by Amendment number and contain marginallines indicating the areas of change.
REMOVE INSERT 1
3.3-6 3.3-6 3.3-13 3.3-13 3.3-25 3.3-25 3.3-43 3.3-43 3.3-47 3.3-47 3.4-23 3.4-23 3.4-30 3.4-30 3.7-14 3.7-14 3.7-15 3.7-15 5.0-13 5.0-13 5.0-19a 5.0-19a l
l
~
I RPS Instrumentation-Operating a
3.3.1 SURVEILLANCE REQUIREMENTS (continued) l l
SURVEILLANCE FREQUENCY SR 3.3.1.6
NOTE--------------_-----
' Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 2 15% RTP.
Verify linear power subchannel gains of the 120 days excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.
NOTES-------------------
1.
The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.
2.
Not required to be performed for logarithmic power level channels until i
2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reducing THERMAL POWER below 1E-4% RTP and only if reattor trip circuit breakers (RTCBs) are closed.
Perform CHANNEL FUNCTIONAL TEST on each 30 days on a channel.
STAGGERED TEST l
BASIS SR 3.3.1.8
.-----------NOTE--------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION of the power 120 days range neu'.ron flux channels.
(continued) l l
l l
l SAN ON0FRE--UNIT 2 3.3-6 Amendment No.127 133,147 3
'RPS Instrumentation-Shutdown l
3.3.2 SURVEILLANCE REQUIREMENTS.(continued)
L SURVEILLANCE FREQUENCY SR 3.3.2.4
NOTE--------------------
. Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform a CHANNEL CALIBRATION on each.
24 months
-logarithmic power channel, including bypass removal function.
i SR 3.3.2.5-
NOTE--------------------
24 months on a i
Neutron detectors-are excluded.
STAGGERED TEST I
BASIS Verify RPS RESPONSE TIME is within limits.
. SAN 0N0FRE--UNIT 2 3.3-13 Amendment No.127,147
l l ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each 30 days on a ESFAS channel.
STAGGERED TEST BASIS SR 3.3.5.3 Perform a CHANNEL FUNCTIONAL TEST of each 120 days ESFAS channel bypass removal function.
SR 3.3.5.4 Perform a CHANNEL CALIBRATION of Function 18 months 5, Recirculation Actuation Signal.
l SR 3.3.5.5 Perform a CHANNEL CALIBRATION of each ESFAS 24 months channel, with the exception of Function 5, including bypass removal functions.
SR 3.3.5.6 Verify ESF RESPONSE TIME is within limits.
24 months on a STAGGERED TEST BASIS SR 3.3.5.7 Perform a CHANNEL FUNCTIONAL TEST on each jOncewithin automatic bypass removal channel.
120 days prior to each reactor startup l
l SAN ON0FRE--UNIT 2 3.3-25 Amendment No. 127,133,147
FH!S 3.3.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform a CHANNEL CHECK on required FHIS 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> radiation monitor channel.
SR 3.3.10.2 Perform a' CHANNEL FUNCTIONAL TEST on required 92 days FHIS radiation monitor channel. Verify radiation monitor setpoint Allowable Values:
Airbome Gaseous: s BE4 cpm above background.
SR 3.3.10.3 NOTE Testing of Actuation Logic shallinclude the actuation of each initiation relay and verification of ths proper operation of each initiation relay.
Perform a CHANNEi. FUNCTIONAL TEST on required FHIS Actuation Logic channel.
18 months SR 3.3.10.4 Perform a CHANNEL FUNCTIONAL TEST on required 18 months FHIS Manual Trip logic.
SR 3.3.10.5 Perform a CHANNEL CALIBRATION on required FHIS 18 months radiation monitor channel.
l SAN ONOFRE-UNIT 2 3.3-43 Amendment No. 127,147
i s,*-
PAM Instrumentation i
3.3.11 Table 3.3.11-1 (page 1 of 1)-
Post Accident Monitoring Instrumentation
[
CONDITIONS REFFRENCED FROM FUNCTION REQUIRED CHANNELS REQUIRED ACTION F.1 1.
Excore Neutron Flux ;
-2 G'
l
- 2.
Reactor Coolant System Hot Leg Temperature 2 (1 per steam
'G j
generator).
. 3.
Reactor Coolant System Cold Leg Temperature 2 (1 per steam G'
generator) 4.
Reactor Coolant System Pressure (wide range)
'2 G
. 5. - Reactor Vessel Water Level 2(d)
H
'6.. Containment Water Level (wide range) 2.
.G l
l
- 7. -Containment Pressure (wide, age) 2.
G 8.
Containment Isolatior. Valve Position
- 2 per pene g n flow G
path 9.
ContainmentAreaRadiation(highrange)'
2 H
l
'10.
Containment Hydrogen Monitors 2
G
- 11. Pressurizer Level-2 G
J
- 12. Iteam Generator Wate'r Level (wide range) 2 per steam generator G'
- 13.. Condensate Storage Tank Level 2
G
- 14. Core Exit Temperature -Quadrant 1 2IC)
G
- 15. Core Exit Temperature -Quadrans 2 2IC)
G
.16.'
Core Exit Temperature - Quadrant 3 2IC)
G
- 17. Core Exit Temperature -Quadrant 4 2(C)
G
- 18. Auxiliary Feedwater Flow 1 per steam generator G
- 19. ContainmentPressure(narrowrange) 2 G
- 20. Reactor Coolant System Subcooling Margin Monitor 2
G
- 21. Pressurizer Safety Valve Position Indication 1 per valve G
22.[ContainmentTemperature 2
G
- 23. Containment Water Level (narrow range) 2 G
- 24. HPSI Flow Cold Leg 1 per cold leg G
- 25. HPSI Flow Hot Leg 1 per hot leg G
- 26. Steam Line Pressure 2 per steam generator G
27.. - Refueling Water Storage Tank Level 2
G (a) Not required for isolation valves whose associated penetration is isolated by at least one closed and
.de activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.
J(b) Only one position indication channel is required for penetration flow paths with only one installed L
contro? room indication channel.
l (r) A channel consists of two or more core exit thermocouples.
f (d)' A channel consists of eight sensors in a probe. A channel is OPERABLE if four or more sensors, one sensor
-in the upper head and three sensors in the lower head are OPERABLE.
L SAN ON0FRE--UNIT 2 3.3-47 Amendment No.12hl39.147 a-
9 RCS Loops-MODE 5, Loops Filled 3.4.7 ACTIONS (continued) j CONDITION REQUIRED ACTION COMPLETION TIME l
l B.
NoSDCtrain/RCS B.1 Suspend all operations Immediately loop in operation, involving reduction in RCS baron t
concentration.
I AM-l b.2 Initiate action to Immediately restore required SDC train /RCSloopto j
operation.
i SURVEI'.i ANCE REQUIREMENTS m kt a,W '
SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify at least one RCS loop or SDC train is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in operation.
SR 3.4.7.2 Verify required SG secondary side water level 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is > 50% (wide range).
I SR 3.4.7.3 Verify the second required RCS loop, SDC train 7 days or steam generator secondary is OPERABLE.
SAN ON0FRE--UNIT 2 3.4-23 Amendment No 127,147
l i
LTOP System 3.4.12.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12.1 Low Temperature Overpressure Protection (LTOP) System RCS Temperature s 256*F LC0 3.4.12.1 No more than two high pressure safety injection pumps shall be OPERABLE, the safety injection tanks shall be isolated or depressurized to less than the limit specified in Figure 3.4.3-2 and at least one of the following overpressure protection systems shall be OPERABLE:
I a.
The Shutdown Cooling System Relief Valve (PSV9349) with:
1)
A lift setting of 406 i 10 psig, 2)
Relief Valve isolation valves 2HV9337, 2HV9339, 2HV9377, and 2HV9378 open, or, b.
The Reactor Coolant System depressurized with an RCS vent of greater than or equal to 5.6 square inches.
APPLICABILITY:
MODE 4 when the temperature of any one RCS cold leg is less than or equal to the enable temperatures specified in Table 3.4.3-1, MODE 5, and MODE 6 when the head is on the reactor vessel and the RCS is not vented.
NOTE----------------------------
SIT isolation or depressurization to less than the Figure 3.4.3-2 limit is only required when SIT pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in Figure 3.4.3-1 and Figure 3.4.3-2.
I' l
l SAN ON0FRE--UNIT 2 3.4-30 Amendment No.127,147
~
AFW System 3.7.5 i
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1-Verify each AFW manual, power operated, and 31 days
automatic, valve in each water flow path and in both steam supply flow paths to the steam turbine. driven pump,.that is not locked, sealed, or otherwise secured in position, is in the correct position.
NOTE--------------------
Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 800 psig in the steam j
generators.
Verify the developed head of each AFW pump 31 days on a at the-flow test point is greater than or STAGGERED TEST equal to the required developed head.
BASIS 1
NOTE--------------------
Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 800 psig in the steam generators.
Verify each AFW automatic valve actuates to 24 months the correct position on an actual or simulated actuation signal, except valves l
HV-8200 and HV-8201.
(continued) 6 SAN ON0FRE--UNIT 2 3.7-14 Amendment No. 127,147 m
e
-n.-
.~, --
l AFB System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.5.4
NOTE--------------------
24 months
. Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 800 psig in the steam generators.
Verify each AFW pump starts automatically on an actual or simulated actuation signal.
l SR 3.7.5.5 Verify the proper alignment of the required Prior to AFW flow paths by verifying flow from the entering MODE 2 condensate storage tank to each steam whenever unit generator, has been in MODE 5 or 6 for
> 30 days SAN ONOFRE--UNIT 2 3.7-15 Amendment No. 127'147
- ~
~..
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only).
The program shall include the following:
a..
Preventive maintenance and periodic visual inspection requirements; and b.
Integrated leak test requirements for each system at refueling cycle intervals or less.
5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity.
Program itself is relocated to the LCS.
5.5.2.10 Inservice Inspection and Testing Program l
This program provides controls for the inservice inspection and testing of ASME Code Class 1, 2, and 3 components including applicable supports. The_ program itself is located in the LCS.
5.5.2.11 Steam Generator (SG) Tube Surveillance Program This program provides controls fo-monitoring SG tube degradation.
Each SG shall be demonstrated OPERABLE by meeting the requirements of Specification 5.5.2.11 and by meeting an augmented inservice' inspection program based on a modification of Regulatory Guide 1.83, Revision 1, which includes at least the following:
a.
SG Sample Selection and Inspection Each SG shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum number of SG specified in Table 5.5.2.11-1 anc; 5.5.2.11-2.
b.
SG Tube Sample Selection and Inspection The SG tube and sleeve minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5.2.11-1 and 5.5.2.11-2.
The inservice inspection cf SG tubes and sleeves shall be performed at the frequencies specified in Specification 5.5.2.11.e and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.2.11.f.
The tubes selected for each inservice l-inspection shall include at least 3% of the total i
I (continued) 127 149,147 SAN ON0FRE--UNIT 2 5.0-13 Amendment No.
1
I Procedures, Programs, and Manuals 5.5 o
5.5 Procedures, Programs, and Manuals (continued) l.
5.5.2.11 Steam Generator Tube Surveillance Program l
1 TABLE 5.5.2.11-1 (page 1 of 1) l i
STEAM GENERATOR TUBE INSPECTION SUPPLEMENTAL SAMPLING REQUIREMENTS ist Sample Inspection 2nd Sample Inspection 3rd Sample Inspection Action Action Actiott Sample 5're Result Required Result Required Result Required A minimum of C-1 None N/A N/t.
N/A N/A 5 tubes per SG C-2 Plug or repair C-1 None N/A N/A i
by sleevitig j
defective tubes Plug or repair by N/A N/A and inspect an sleeving defective additional 25 tubes and C-1 N/A l
tubes in this inspection an
$G.
addltional 45 C-2 Plug or repair tubes in this $G.
by sleeving defective tubes.
C-3 Perform action for C-3 result of first sample.
C-3 Perform N/A N/A action for C-3 result of first sample.
C-3 Inspect all All other SGs None N/A N/A tubes in this C-1
$G, plug or repair by sleeving Some SGs C-2 Perform N/A N/A defective tubes but no other action for
~
and inspect 25 is C-3 C-2 result of tubes in each second other SG.
sample.
Notification to NRC Additional SG Inspect all tubes pursuant to is C-3 in each $G and N/A N/A 10CFR50.73 plug or repair by l
sleeving defective tubes.
Notification to NRC pursuant to 10CFR50.73.
l S=3N/n%WhereNisthenumberofSGsintheunitandnisthenumberof SGs inspected during inspection period.
(continued)
SAN ON0FRE--UNIT 2 5.0-19a Amendment No.149,147
7 (18) Initial Test Proaram (Section 14. SER)
SCE shall conduct the post-fuel loading initial test program (set forth in Section 14 of the San Onofre Units 2 and 3 Final Safety Analysis Report.
as amended) without making any major modifications to this program l
l unless such modifications have been identified and have received prior NRC approval. Major modifications are defined as:
a.
Elimination of any test identified in Section 14 of the Final Safety Analysis Report, as amended, as being essential.
l b.
Modification of test objectives, methods, or acceptance criteria for any test identified in Section 14 of the Final Safety Analysis l
Report, as amended, as being essential.
c.
Performance of any test at a power level different than that described in the test procedure, d.
Failure to complete any tests included in the de= ribed program (planned or scheduled for power levels up to the authorized power level).
(19) NUREG-0737 Conditions (Section 22)
Each of the following conditions shall be completed to the satisfaction of the NRC. Each item references the related subpart of Section 22 of the SER and/or its supplements.
a.
Shift Technical Advisor (l.A.1.1. SSER #1)
SCE shall provide a fully trained on-shift technical advisor to the shift supervisor (watch engineer),
b.
Shift Mannina (l.A.1.3. SSER #1. SEER #5)
Deleted.
I l
l Amendment No. 8: 147
. - ~ -.
c.
Indeoendent Safetv Engir.;;;ina Groun (l.B.1.2. SSER #1)
SCE shall have an on-site independent safety engineering group.
d.
Procedures for Transients and Accidents (l.C.1. SSER #1.
SSER #2. SSER #5)
By May 1,1982, SCE shall provide emergency procedure guidelir.es. Emergency procedures based on guidelines approved by the NRC shall be implemented prior to startup following the first refueling outage, e.
Procedures for Verifvina Correct Performance of Ooeratglg l
Activities (l.C.8. SSER #1)
I Prior to fuel loading, SCE shall implement a system for verifying the correct performance of operating activities, and shall keep the system in effect thereafter, f.
Control Room Design Review (l.D.1. SSER #1) l Prior to exceeding five (5) percent power, SCE shall:
1.
Prioritize the control room annunciator windows.
l Amendment No.147
. ~
car %
\\
UNITED STATES g
]
NUCLEAR REGULATORY COMMIS810N 4
I l
WASHINGTON, D.C. 30006 4001 e$
l SOUTHERN CALIFORNIA EDISON COMPANY l
)
SAN DIEGO GAS AND ELECTRIC COMPANY THE CITY OF RlVERSIDE. CALIFORNIA THE CITY OF ANAHEIM. CALIFORNIA DOCKET NO. 50-382 l
SAN ONOFRE NUCI PAR GENERATING STATION. UNIT NOJ AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.139 License No. NPF-15 1.
The Nuclear Regulatory Commission (the Commission) has found that:
l A.
The application for amendment by Southem Califomia Edison Company, et al.
l (SCE or the licensee) dated June 30,1997, complies with the standardt and requirements of the Atomic Energy Act of 1954, as amended (the Act), and #
)
l Commission's regulations set forth in 10 CFR Chapter I; i
B.
The facility will operate in conformity with the application, the provisions of 1 Act, and the ruhs and regulations of the Commission; C.
There is reasonable assurance (i) that the activities authorized by this amendment car. be conducted veithout endangering the health and safety of the l
public, and (ii) that such activities will be conducted in compliance with the l
Commission's regulations; D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and l'
E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the i
Commission's regulations and all applicable requirements have been satisfied.
l f
4
l 1
. 2.
Accordingly, the license is amended changes to the Technical Specifications as l
Indicated in the attachment to this license amendment, and paragraph 2.C(2) of Facility Operating License No. NPF-15 is hereby amended to read as follows:
r (2)
Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No.
139, are hereby incorporated in the license. Southem Califomia Edison Company shall operate the facility in accordance with the Technical l
Specifications and the Environmental Protection Plan.
3.
This license amendment is effective as of the date of its issuance and is to be l
implemented within 30 days of its date of issuance.
i i
FOR THE NUCLEAR REGULATORY COMMISSION N )
j James W. Clifford, Senior Project Manager Project Directorate IV-2 Division of Reactor Projects Ill/lV Office of Nuclear Reactor Regulation l
Attachment:
Changes to the Technical Specifications Date of issuance:
December 22, 1998 i
4 i
e e
ATTACHMENTTO LICENSE AMENDMENT AMENDMENT NO.139 TO FACILITY OPERATING LICENSE NO. NPF-15 DOCKET NO. 50-362 Revise Appendix A Technical Specifications by removing the pages identified below and inserting the enclosed pages. The revised pages are identified by Amendment number and contain marginal lines indicating the areas of change.
REMOVE INSERT 3.3-6 3.3-6
- 3.3-13 3.3-13 3.3-25 3.3-25 3.3-43 3.3-43 3.3-47 3.3-47 3.4-23 3.4-23 3.4-30 3.4-30 3.7-14 3.7-14 3.7-15 3.7-15 5.0-13 5.0-13 5.0-19a 5.0-19a 1
a l
RPS Instrumentation-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued) 1 SURVEILLANCE FREQUENCY l
NOTE--------------------
I Not required to be performed until 1
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 2 15% RTP.
Verify linear power subchannel gains of 120 days the excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.
NOTES-------------------
1.
The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.
2.
Not required to be performed for logarithmic power level channels until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reducing THERMAL POWER below 1E-4% RTP and only if reactor trip circuit breakers I
(RTCBs) are closed.
Perform CHANNEL FUNCTIONAL TEST on each 30 days on a channel.
STAGGERED TEST l
l BASIS SR 3.3.1.8
NOTE--------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION of the power 120 days range neutron flux channels.
I (continued)
SAN ON0FRE--UNIT 3 3.3-6 Amendment No.116 122,139 3
i.
L o
RPS Instrumentation-Shutdown 3.3.2 0
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.2.4
NOTE--------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
1 Perform a CHANNEL CALIBRATION on each 24 months logarithmic power channel, including bypass removal function.
NOTE--------------------
24 months on a Neutron detectors are excluded.
STAGGERED TEST BASIS Verify RPS RESPONSE TIME is within limits.
l l
SAN ON0FRE--UNIT 3 3.3-13 Amendment No.116,139 l
l l
ESFAS Instrumentation l
3.3.5.
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.5.2 Perform'a CHANNEL FUNCTIONAL TEST of each 30 days on a ESFAS channel.
STAGGERED TEST BASIS i-l' SR 3.3.5.3 Perform a CHANNEL FUNCTIONAL TEST of each 120 days ESFAS channel bypass removal function..
.SR 3.3.5.4 Perform a CHANNEL CALIBRATION of Function 18 months L
- 5. Recirculation Actuation Signal.
l L
.SR 3.3.5.5 Perform'a CHANNEL CALIBRATION of each 24 months l
ESFAS channel, with the exception of l'
Function 5, including bypass removal functions.
l l
SR 3.3.5.6 Verify ESF RESPONSE TIME is within 24 months on a limits.*
STAGGERED TEST BASIS
.SR -3.3.5.7 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel.
120 days prior to each reactor E.
startup
- Verification of the RESPONSE TIME of the 30 subgroup relays identified in the February 18, 1997 Edison letter is not ap)licable until return to Mode 4 from the Unit 3 Cycle 9 refueling outage, wit 1 the additional commitments
~
made in the February 18. 1997 letter. -The safety justification for not
- - performing this testing is also included in the February 18, 1997 letter.
- ~
f i
' SAN ON0FRE--UNIT 3 3.3-25 Amendment No.116,122 l275 i
139 I - - -
6 3
,w.
,..u,,-
-,,y
,w
FHIS 3.3.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY l
SR 3.3.10.1 Perform a CHANNEL CHECK on required FHIS 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> i
j radiation monitor channel.
. SR 3.3.10.2 '
Perform a CHANNEL FUNCTIONAL TEST on 92 days required FHIS radiation monitor channel. Verify radiation monitor setpoint Allowable Values:
?
l Airbome Gaseous: s 6E4 cpm above background.
i SR ' 3.3.10.3 NOTE Testing of Actuation Logic shall include the actuation of each initiation relay and verification of the proper l
operation of each initiation relay.
1 i
l Perform a CHANNEL FUNCTIONAL TEST on required FHIS Actuation Logic channel.
18 months
- SR 3.3.10.4 Perform a CHANNEL FU' NCTIONAL TEST on 18 months required FHIS Manual Trip logic.
i hr E
SR 3.3.10.5 Perform a CHANNEL CAllBRATION on required 18 months FHIS radiation monitor channel.
i SAN ON0FRE--UNIT 3 3.3-43 Amendment No.116,139
o, PAM Instrumentation o '-
3.3.11 Table 3.3.11-1 (page 1 of 1)
Post Accident Monitoring Instrumentation COND1110NS I
REFERENCED FROM FUNCTION REQUIRED CHANNELS REQUIRED AC710N F.1 1.
Excore Neutron Flux 2
G 2.
Reactor. Coolant System Hot Leg Temperature 2 (1 per steam G
generator) 3.
Reactor Coolant System Cold Leg Temperature 2 (1 per steam G'
generator) 4 ReactorCoolantSystemPressure(widerange) 2 G
'5.
Reactor Vessel Water Level 2(d) g 6.
Containment Water Level (wide range)-
2 G
l 7.
ContainmentPressure(widerange) 2 G
8.
Containment Isolation Valve Position 2 per ne g n flow G
l 9.
Containment Area Radiation (high range) 2 H
- 10. Containment Hydrogen Monitors 2
G
- 11. Pressurizer Level 2
G
- 12. Steam Generator Water Level (wide range) 2 per steam generator G
- 13. Condensate Storage Tank Level 2
G
- 14. Core Exit Temperature - Quadrant 1 2(C)
G
.15.
Core Exit Temperature - Quadrant 2 2(C)
G
- 16. Core Exit Temperature -Quadrant 3 2(c) g 17.' Core Exit Temperature - Quadrant 4 2(C)
G
- 18. Auxiliary Feedwater Flow I per steam generator G
- 19. Containment Pressure (narrew range) 2 G
- 20. Reactor Coolant System Subcooling Margin Monitor 2
G i
- 21. -Pressurizer Safety Valve Position Indication 1 per valve G
- 22. - Containment Temperature-2 G
- 23. Containment Water Level (narrow range) 2 G
- 24. HPS! Flow Cold Leg 1 per cold leg G
- 25. HPS! Flow Hot Leg 1 per hot leg G
- 26. - Steam Line Pressure 2 per steam generator G
!~
- 27. Refueling Vater Storage Tank Level 2
G (a) Not required for isolation valves whose associated penetration is isolated by at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.
~ (b) -Only one position indication channel is required for penetratica flow paths with only one installed control room indication channel.
(c) A channel consists of two or more core exit thermocouples.
(d) A channel consists of eight sensors in a probe. A channel is OPERABLE if four or more sensors, one sensor in the upper head and three sensors in the lower head are OPERABLE.
-SAN ON0FRE--UNIT 3-3.3-47 Amendment No.1163119,139
.,m RCS Loops-MODE 5, Loops Filled y
3.4.7 L-ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.
NoSDCtrain/RCS B.1 Suspend all operations Immediately loop in operation.
involving reduction in RCS boron concentration.
AliQ B.2 Initiate action to Immediately restore required SDC train /RCSloopto operation.
L SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY l
SR 3.4.7.1 Verify at least one RCS loop or SDC train 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> l
i is in operation.
L SR 3.4.7.2 Verify required SG secondary side water 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> level 1: > 50% (wide range).
l l
l SR 3.4.7.3 Verify the second required RCS loop, S0C 7 days train or steam generator secondary is OPERABLE.
l l-1 i
t s
SAN ONOFRE--UNIT 3 3.4-23 Amendment No.116,139
l' LTOP System 3.4.12.1 4
i 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12.1 Low Temperature Overpressure Protection (LTOP) System l
RCS Temperature s 246 F LC0 3.4.12.1 '
No more than two high pressure safety injection pumps shall be OPERtBLE, the safety injection tanks shall be isolated or o
i depressurized to less than the limit specified in Figure 3.4.3-2 and at least one of the following overpressure l
protection systems shall be OPERABLE:
a.
The Shutdown Cooling System Relief Valve (PSV9349) with:
1)
A lift setting of 406
- 10 psig, 2)
Relief Valve isolation valves 3HV9337, 3HV9339, 3HV9377, l
and 3HV9378 open, or, i
l b.
The Reactor Coolant System depressurized with an RCS vent of l
greater than or equal to 5.6 square inches.
I i
APPLICABILITY:
MODE 4 when the temperature of any one RCS cold leg is less i
than or equal to the enable temperatures specified in Table j
3.4.3-1, MODE 5, and MODE 6 when the head is on the reactor vessel and the RCS is not vented.
NOTE----------------------------
l SIT isolation or depressurization to less than the Figure 3.4.3-2 limit is only required when SIT pressure is greater than or equal to the maximum RCS 3ressure for the existing l
RCS cold leg temperature allowed )y the P/T limit curves provided in Figure 3.4.3-1 and Figure 3.4.3-2.
d d
SAN ON0FRE--UNIT 3 3.4-30 Amendment No. 116,139 1
0
i I'**
AFW System 3.7.5 1
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and 31 days automatic valve in each water flow path and in both steam supply flow paths to the steam turbine driven aump,' that is not locked, sealed, or otlerwise secured in position, is in the correct position.
l SR. 3.7.5.2
NOTE--------------
Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> i
after reaching 800 psig in the steam generators.
Verify the developed head of each AFW pump 31 days on a at the flow test point is greater than or STAGGERED TEST equal to the required developed head.
BASIS SR 3.7.5.3
NOTE--------------------
Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 800 psig in the steam generators.
Verify each AFW automatic valve actuates to 24 months the correct position on an actual or simulated actuation signal, except valves l
HV-8200 and HV-8201.
l (continued) l i
r SAN ON0FRE--UNIT 3 3.7 14 Amendment No. 116,139
i
)
'8 3, ;.
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY L
NOTE--------------------
24 months
. Not required to be performed'for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />
~ fter reaching 800 psig in the steam
)
a generators.
Verify each AFW pump starts automatically on an actual or simulated actuation signal.
l "l-
-SR 3.7.5.5 Verify the proper alignment of the required Prior to
'AFW flow paths by verifying flow from the entering MODE 2 condensate storage' tank to each steam whenever unit 1
generator.
has been in L
MODE 5 or 6 for
> 30 days 1
l l
i SAN ON0FRE--UNIT 3 3.7-15 Amendment No. 116,139 i
i 0
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outsida Containment Program (continued) system (post-accident sampling return piping only). The program shall include the following:
a.
Preventive maintenance and periodic visual inspection requirertents; and b.
Integrated leak test requirements for each system at refueling cycle intervals or less, i
5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to en e.e containment structural integrity.
Program itself is reiocated to the LCS.
5.5.2.10 Inservice Inspection and Testing Program j
l This program provides controls for the inservice inspection and testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program itself is located in the LCS.
5.5.2.11 Steam Generator (SG) Tube Surveillance Program This program provides controls for monitoring SG tube degradation.
Each SG shall be demonstrated OPERABLE by meeting the requirements of Specification 5.5.2.11 and by meeting an augmented inservice inspection program based on a modification of Regulatory Guide 1.83, Revision 1, which includes at least the following:
a.
SG Sample Selection and Inspection Each SG shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum number of SG specified in Table 5.5.2.11-1 and 5.5.2.11-2.
I b.
SG Tube Sample Selection and Inspection The SG tube and sleeve minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5.2.11-1 and 5.5.2.11-2.
l The inservice inspection of SG tubes and sleeves shall be i
performed at the frequencies specified in Specification 5.5.2.11.e and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.2.11.f.
The tubes selected for each inserv'.e inspection shall include at least 3% of the total (continued)
SAN ON0FRE--UNIT 3 5.0-13 Amendment No.116 132,139 5
Procedures, Programs, and Manuals t *. **
5.5 h
5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator Tube Surveillance Program TABLE 5.5.2.11-1(page1of1)-
STEAM GENERATOR TUBE INSPECTION SUPPLEMENTAL SAMPLING REQUIREMENTS 1st Sample Inspection 2nd Sample Inspection 3rd Sample Inspection Action Action Action Sample Size Result Required Result Required Result Required A minimum of C-1 None N/A N/A N/A.
N/A-S tubes per i
SG C-2 Plug or repair C-1 None N/A N/A by sleeving defective tubes Plug or repair by N/A N/A and inspect an sleeving additional 25 defective tubes C-1 N/A-l tubes in this and inspection an SG.
additional 45 C-2 Plug or repair tubes in this SG.
by sleeving defective tubes.
C-3 Perform action for C-3 result of first sample.
C-3 Perform N/A N/A action for C-3 result of first sample.
C-3 Inspect all All other SGs None N/A N/A I
tubes in this C-1 l
3G, plug or repair by l
sleeving Some SGs C-2 Perform N/A N/A l
defective tubes but no other action for l
and inspect 25 is C-3 C-2 result of i
tubes in each second I
other SG.
sample.
l Notification l-to NRC Additional SG Inspect all tubes pursuant to is C-3 in each SG and N/A N/A j
10CFR50.73 plug or repair by l
sleeving defective tubes.
Notification to l
NRC pursuant to
{
l S=3N/n%WhereNisthenumberofSGsintheunitandnisthenumberof SGs inspected during inspection period.
i i
(continued)
SAN ONOFRE--UNIT 3 5.0-19a Amendment No. 182,139 4
y
,e,