ML20217A823
| ML20217A823 | |
| Person / Time | |
|---|---|
| Site: | San Onofre  |
| Issue date: | 09/16/1997 |
| From: | SOUTHERN CALIFORNIA EDISON CO. |
| To: | |
| Shared Package | |
| ML20046D781 | List: |
| References | |
| NUDOCS 9709230004 | |
| Download: ML20217A823 (63) | |
Text
- _ - - - _ _ _ _ _ _ _ _ -
NPF-10/15-487
)
ATTACHMENT A (Existing Specifications)
Unit 2
{R09230004 970916 p
ADOCK 05000361 PDR
RCS Operational LEAKAGE 3.4.13 3.A REACTOR COOLANT SYSTEM (kCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:
a.
No pressure boundary LEAKAGE; b.
1 gpm unidentified LEAKAGE; c.
10 gpm identified LEAKAGE; d.
I gpm total primary to secondary LEAKAGE through all steam generators (SGs); and e.
720 gallons per day (1/2 gpm) primary to secondary LEAKAGE t'iroagh any one SG.
APPLICABILITY:
MODES 1, 2, 3, and 4.
ACTIONS l'
CONDITION REQUIRED ACTION COMPLETION TIME A.
RCS LEAKAGE not within A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limits for reasons within limits.
other than pressure boundary LEAKAGE.
B.
Required Action and B.1 Be in MODE 3.
6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A AND not met.
B.2 Be in MODE 5.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> QB Pressure boundary LEAKAGE exists.
SAN ON0FRE--UNIT 2 3.4-37 Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedures,-Programs, and Manuals 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 o
integrity.
Program itself is relocated to the LCS.
5.5.2.10 Inservice Testing Program L
This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports.
Program itself is relocated to 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 meetina 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 no,ber of SG 4
e specified in Table 5.5.2.11-1.
i l
b.
SG Tube Sample Selection and Inspection
.1 The SG tube minimum sample size, inspection result j
classification, and the corresponding action required shall be as specified in Table 5.5.2.11-1.
The inservice inspection of SG tubes 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.ll.f.
The tubes selected for each i
inservice inspection shall include at least 3% of the total I
l (continued) l
~
SAN ONOFRE--UNIT 2 5.0-13 Amendment No. 127 i
Procedures,. Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) number of tubes in all SGs; the tubes selected for these inspections shall be selected on a rsndom basis except:
1.
Where experience in similar plants with similar water chemistry indicates critical areas to be inspected, then at least 50% of the tubes inspected shall be from the critical areas; 2.
The first sample of tubes selected for each inservice inspection (subsequent to the preservice inspection) of l
each SG shall include:
a)
All nonplugged tubes that previously had detectable wall penetrations (greater than 20%),
b)
Tubes in those areas where experience has indicated potential problems, and c)
A tube inspection (pursuant to Specification 5.5.2.11.f) shall be performed on each selected tube.
If any selected tube does not permit the passage of the eddy current probe for a tube inspection,-this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection, c.
Examination Results The results of each sample inspection shall be classified into one of the following three categories:
C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective.
C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.
C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.
(continued)
SAN ONOFRE--UNIT 2 5.0-14 Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued)
...........................-N0TE--------------------------
In ell inspections, previously degraded tubes me exhibit significant (greater than 10%) further wall penetrations to be included in the above percentage calculations.
d.
Supplemental Sampling Requirements The tubes selected as the second and third samples (if requird by Table 5.5.2.11-1) may be subjected to a partial tube inspection provided:
1.
The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfections were previously found, and 2.
The inspections include those portions of the tubes where imperfections were previously found, e.
Inspection Frequency The above required inservice inspections of the SG tubes shall be performed at the following frequencies:
1.
The first inservice inspection shall be performed after 6' effective full power months but within 24 calendar months of initial critically. Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection.
!f two consecutive inspections, not including the preservice inspection, result in all inspections results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months; 2.
If the results of the inservice inspection of a SG conducted in accordance with Table 5.5.2.11-1 at month intervals fall in Category C-3, the inspection shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.2.ll.f, the interval may then be extended to a maximum of once per 40 months; and s
(continued)
SAN ON0FRE--UNIT 2 5.0-15 Amendment No. 127
4 Procedures, Programs, and Manuals 4
5.5 5.5-Procedures, Programs, and Mandals s
i 5.5.2.11-Steam Generator (SG) Tube Surveillance Program (continued) t l
3.
Additional, unscheduled inservice inspections shall be l
performed on each SG in accordance with the first sample J
inspection specified in Table 5.5.2.11-1 during the shutdown subsequent to any of the following conditions:
a)
Primary-to secondary tubes leak (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of Technical Specification 3.4.13, or j
b)
A seismic occurrence greater than the Operating Bar.ls Earthquake, or c)
A loss-of-coolant accident requiring actuation of I
the Engineered Safety Features, or I
d)
A main steam line or feedwater line break.
4.
The provisions of Technical Specifications Surveillance Requirement 3.0.2 are applicable to SG Tube Surveillance inspection frequencies except those established by Category C-3 inspection results, f.
Acceptance Criteria 1.
Terms as used in this specification will be defined as follows:
a)
Degradation - A service-induced cracking, wastage, wear, or general corrosion occurring on either inside or outside of a tube; b)
Degraded tube - A tube containing imperfections greater than or equal to 20% of the nominal wall thickness cause by degradation; c)
% Degradation - The percentage of the tube wall thickness affected or removed by degradation; d)
Defect - An imperfection of such severity that it exceeds the plugging limit. A tube containing a defect is defective; e)
Imperfection - An exception to the dimensions, finish, or contour of a tube from that required by fabrication drawings or specifications.
Eddy-(continued)
SAN ON0FRE--UNIT 2 5.0-16 Amendment No. 127
i Procedures, Programs, and Manuals a
5.5 l
5.5 Procedures, Programs, and Manuals l
l 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) current testing indications below 20% of the nominal tube wall thickness, if detectable, may be considered as imperfections; f)
Plugging Limit The im)erfection depth at or beyond which the tube siall be removed from service and is equal to 44% of the nominal tube wall thickness g)
Preservice Inspection An inspection of the full length of each tube in each SG perf)rmed by eddy-cutrent techniques prior to service to establish a basciine condition cf the tubing.
This inspection 62, be performed prior to initial MODE 1 sperating using the equipment and techniques expected to be used during subsequent inservice inspections.
These examinations may be performed prior to steam generator installation.
h)
Tube insoection An inspection of the SG tube from the po'nt of entry (hot leg side) cornpletely around the U bend to the top support of the cold leg and 1)
Unserviceable - The condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operational Basis Earthquake, a loss-of-coolant accident, or a steam line of feedwater line break accident as specified in Specification 5.5.2.11.e.
2.
The SG shall be determined OPERABLE after completing the corresponding actions (plug all tubes exceeding the plugging limit and all tubes containing through wall cracks) required by Table 5.5.2.11-1.
g.
Report.t The content and frequency of writta reports shall be in accordance with Technical Specification 5.7.2, "Special Reports."
(continued)
SAN ONOFRE -UNIT 2 5.0-17 Amendment No. 127
Procedures, Programs, and Manuals 5,5 4
1 1
5.5 Procedures Programs, and Manuals i
5.5.2.11 Steam Generator Tube Surveillance Program i
j TABLE 5.2.11 1 (page 1 of 1) l STEAM GENERATOR TUBE INSPECTION j
SUPPLEMENTAL SAMPLING REQUIREMENTS-1 ist Sanple inspection 2nd senple Inspection 3rd Sanple Inspection Action Action Action senple $lte Result kequired Result Required Result Required i
A mininum of C1 None N/A N/A N/A N/A
$ tubes per SG C2 Plug C1 None N/A N/A defective i
tubes and Plug W/A N/A Inspect en defective E
edditional 25 tubes and C+1 N/A 3
tubes in this inspection en s
$0 additional 6$
C2 Plug i
tubes in this defective
$0.
tubes.
C3 Perform action fur C 3 result of j
first senple.
1' C3 Perform N/A N/A action for C 3 result of first sample, j
C3 Inspect all All other $Gs None N/A N/A i
tubes in this C1 l
$G, plug defective i
tubes and Some $Gs C 2 Perform N/A N/A Inspect 28 but no other action for tubes in each is C 3 C 2 result of other SG.
second
- sanple, i
Notification to NRC Additional $G Inspect all l
prsuant to is C 3 tubes in each N/A N/A loCFR50.72
$G and plug l
defectives.
tubes Notification to NRC pursuant to j
ioCra50.72.
S = 3 N/n % Where N is the number of SGs in the unit and n is t ha number of j
SGs inspected during inspection period.
i I
e i
1 i
i (continued) l SAN ON0FRE-UNIT 2 5.0-18 Amendment No. 127 i
i ia-....-,-..,,.-
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) 5.5.2.11.1 The inservice inspection may be limited to one SG on a rotating schedule encompassing 6% of the tubes if the results of the first or previous inspections indicate that all SGs are j
performing in a like manner.
Note that under some circumstances, the operating conditions in one SG may be found to be more severe than those ih the other SG.
Under such circumstances the sample sequence shall be modified to inspect the most severe conditions.
5.5.2.11.2 The other SG not inspected during the first inservice inspection shall be inspected.
Th9 third and subsecuent inspections should follow the instructions describec in Specification 5.5.2.11.1 above.
j 5.5.2.12 Ventilation Filter Testing Program (VFTP)
This Program establishes the required testing of the Engineered Safety feature filter ventilation systems, " Control Room Emergency s
Air Cleanup System" and " Fuel Handling Building Post-accident Cleanup Filter System," in accordance with Regulatory Guide 1.52 Revision 2, and ASME N510-1989. The frequency of testing shall be in accordance with Regulatory Guide 1.52, Revision 2.
As a minimum the VFTP program shall include the following:
a.
Inplace testing of the high efficiency particulate air (HEPA) filters to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME i
N510-1989; and b.
Inplace testing of the charcoal adsorber to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989; and c.
Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested at the appropriate temperature and reistive humidity in accordance with ASTM D3803 1989 to show acceptable methyl iodide penetration; and d.
Testing to demonstrate the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers, when tested at the appropriate system flewrate, is acceptable in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989.
(continued)
SAN ON0FRE--UNIT 2 5.0-19 Amendment No. 127
i Reporting Requirements 5.7 5.7 Reporting Requirements (continued) i j
5.7.2 Special Reports i
Special Reports may be required covering inspection, test, and maintenance activities. These special reports are determined on an individual basis for each unit and their preparation and submittal
]
are designated in the Technical Specifications.
]
1 Special Reports shall be submitted to the U. S. Nuclear Regulatory l
Commissinn, Attention: Document Control Desk, Washington, D. C.
20555, with a copy to the Regional Administrator of the Regional J
i Office of the NRC, in accordance with 10 CFR 50.4 within the time j
period specified for each report.
i The following Special Reports shall be submitted:
a.
When a pre planned alternate method of monitoring post-accident instrumentation functions is required by Condition B 4
i-or Condition H of LCO 3.3.11, a report shall be submitted within 30 do,'s from the time the action is required.
The report shall outline the action taken, the cause of the inoperability, and the plans and schedule for restoring the i
instrumentation channels of the function to OPERABLE status.
b.
Any abnormal degradation of the containment structure detected l
during the tests required by the Pre Stressed Concrete Containment Tendon Surveillance Program shall be reported to i
the NRC within 30 days.
The report shall include a 1
description of the tendon condition, the condition of the concrete (especially at '.endon anchorages), the inspection 1
procedures, the tolerances on cracking, and the corrective i
action taken.
I_
c.
Following each inservice inspection of steam generator (SG) tubes, in accordance with the SG Tube Surveillance Program, the number of tubes plugged and tubes sleeved in each SG shall be reported to the NRC within 15 days. The com)1ete results
.of the SG tube inservice inspection shall be suamitted to the NRC within 12 months following the completion of the j
inspection.
The report shall include:
1.
Number and extent of tubes inspected, and 1
2.
Location and percent of wall-thickness penetration for each indication of an imperfection, and l-3.
Identification of tubes plugged and tbbes sleeved.
4 (continued) i l
SAN ON0FRE--UNIT 2 5.0-30 Amendment No. 127 1
._,,._,..-_.,_..-._.-.-._--,.-.---,-----,_.-r._-...--,
NPF 10/15 481 ATTACHMENT B (ExistingSpecifications) 1
hh$h RCS Operational LEAKAGE 3.4.13 1
3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LC0 3.4.13 RCS operational LEAKAGE shall be limited to:
a.
No pressure boundary LEAKAGE; b.
1 gpm unidentified LEAKAGE; c.
10 gpm identified LEAKAGE d.
I gpm total primary to secondary LEAKAGE through all steam generators (SGs); and e.
720 gallons per day (1/2 gpm) primary to secondary LEAKAGE through any one SG.
APPLICABILITY:
MODES 1, 2, 3, and 4.
l ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
RCS LEAKAGE not within A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limits for reasons within limits.
other than pressure boundary LEAKAGE.
B.
Required Action and B.1 Be in MODE 3.
6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A MQ not met.
B.2 Be in MODE 5.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> DE Pressure boundary LEAKAGE exists.
SAN ONOFRE--UNIT 3 3.4-37 Amendment No. 116 1
Proccdures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accidentsamplingreturnpipingonly).
The program sua11 include the following:
i a.
Preventive maintenance and periodic visual inspection requirements; and b.
Integrated leak test requirements for each system at refueling l
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 i
corrosion protection medium, to ensure containment structural integrity.
Program itself is relocated to the LCS.
5.5.2.10 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports.
Program itself is relocated to the LCS.
5.5.2.11 Steam Generator (SG) Tube Surveillance Prograu This program providos 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.
b.
SG Tube Sample Selection and Inspection The SG tube minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5.2.11-1.
The inservice _ inspection of SG tubes shall be performed at the frequencies specified in Specification 5.5.2.ll.e and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.2.ll.f.
lhe tubes selected for each inservice inspection shall include at least 3% of the total (continued)
SAN ON0FRE--UNIT 3 5.0-13 Amendment No. 116
Procedures, Programs, and Manuals 5.5 5.5 Prog 1ures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) l i
number of tubes in all SGs; the tubes selected for these inspections shall be selected on a random basis except:
1.
Where experience in similar plants with similar water chemistry indicates critical areas to be inspected, then at least 50% of the tubes inspected shall be from the critical areast 2.
The first sample of tubes selected for each inservice ins mction (subsequent to the preservice inspection) of eac1 SG shall include:
a)
All nonplugged tubes that previously had detectable wall penetrations (greater than 20%),
b)
Tubes in those areas where experience has indicated potential problems, and 1
c)
A tube inspection (pursuant to Specification
{
5.5.2.ll.f) shall be performed on each selected tube.
If any selected tube does not parmit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection, c.
Examination Results The results of each sample inspection shall be classified into J
one of the following three categories:
C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective.
i C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.
C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.
(continued)
SAN ON0FRE--UNIT 3 5.0-14 Amendment No, 116
Procedures Program?, and Manuals 5.5 5.5 Procedures Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued)
............................N0TE In all inspections, previously degraded tubes must exhibit significant (greater than 10%) further wall penetrations to be l
included in the above percentage calculations.
'I d.
Supplemental Sampling Requirements The tubes selected as the second and third samples (if required by Table 5.5.2.11-1) may be subjected to a partial tube inspection provided:
1.
The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperTections were previously found, and 2.
The inspections include those portions of the tubes where imperfections were previously found.
e.
Inspection Frequency The above required inservice inspections of the SG tubes shall be performed at the following frequencies:
1.
The first inservice inspection shall be performed after 6 effective full power months but within 24 calendar months of initial critically.
Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection.
if two consecutive inspections, not including the preservice inspection, result in all inspections results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months; 2.
If the results of the inservice inspection of a SG conducted in accordance with Table 5.5.2.11-1 at 40-month intervals fall in Category C-3, the inspection shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.2.ll.f. the interval may then be extended to a maximum of once per 40 months; and (continued)
SAN ON0FRE--U:11T 3 5.0 15 Amendment No. 116
r Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals I
l 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) 3.
Additional, unscheduled inservice inspections shall be performed on each SG in accordance with the first sample inspection specified in Table 5.5.2.11 1 during the shutdown subsequer.t to any of the following conditions:
a)
Primary-to secondary tubes leak (not including leaks originatinq' limits of Technical Specification from tube to tube sheet welds) in excess of the 3.4.13, or b)
A seismic occurrence greater than the Operating Basis Earthquake, or c)
A-loss of coolant accident requiring actuation of the Engineered Safety Features, or d)
A main steam line or feedwater line break.
4.
The provisions of Technical S)ecifications Surveillance Requirement 3.0.2 are applica)1e to SG Tube Surveillance inspection frequencies except those established by Category C-3 inspection results.
f.
Acceptance Criteria 1.
Terms as used in this specification will be defined as follows:
a)
Degradation - A service-induced cracking, wastage, wear, or general corrosion occurring on either l
inside or outside of a tube; b)
Degraded tube - A tube containing imperfections greater than or equal to 20% of the nominal wall thickness cause by degradation; c)
% Degradation - The percentage of the tube wall thickness affected or removed by degradation; d)
Defect An imperfection of such severity that it exceeds the plugging limit. A tube containing a
[,
defect is defective; e)
Imperfection - An exception to the dimensions, finish, or contour of a tube from that required by fabrication drawings or specifications.
Eddy-3 (continued)
SAN ON0FRE--UNIT 3 5.0-16 Amendment No. 116 1
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) current testing indications below 207,of the nominal tube wall thickness, if detectable, may be considered as imperfections; f)
Plugging Limit - The im)erfection depth at or beyond which the tube sla11 be removed from service and is equal to 44Y. of the nominal tube wall thickness; g)
Preservice Inspection An inspection of the full length of each tube in each SG performed by eddy-current techniques prior to service to establish a baseline condition of the tubing. This inspection shall be performed prior to initial MODE 1 operating using the equipment and techniques expected to be used during subsequent inservice inspections.
These examinations may be performed prior to steam generator installation.
h)
Tube inspection - An inspection of the SG tube from the point of entry around the U-bend to the(hot leg side) completely top support of the cold leg; and i)
Unserviceable - The condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operational Basis Earthquake, a loss of coolant accident, or a steam line of feedwater line break accident as specified in Specification 5.5.2.ll.e.
2.
The SG shall be determined OPERABLE after completing the corresponding actions (plug all tubes exceeding the plugging limit and all tubes containing through wall cracks) required by Table 5.5.2.11-1.
g.
Reports The content and frequency of written reports shall be in accordance with Technical Specification 5.7.2, "Special Reports."
(continued)
SAN ONOFRE--UNIT 3 5.0-11 Amendment No, 116
i Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator Tube Surveillance Program TABLE 5.2.11-1 (page 1 of 1)
STEAM GENERATOR 10BE INSPECTION SUPPLEMENTAL SAMPLING REQUIREMENTS ist Sample Inspection 2nd Sanple inspection 3rd Sanple Inspection Action Action Action Sample $1re Result Required Result Required Result Required A minioun of C1 None N/A N/A N/A N/A
$ tubes per
$G C2 Plug C1 None N/A N/A defective tubes and Plug N/A N/A inspect en defective additional 25 tubes and C1 N/A tubes in this inspection 6n
$G edditional 4$
C2 Plug tubes in this defective SG.
tubes.
C3 Perform action for C 3 result of first sanple.
C3 Perform N/A N/A action for C 3 result of j
first sanple.
C3 Inspect att Att other $Gs None N/A N/A tubes in this C1
$G, plug defective tubes and some $Gs C 2 Perform N/A N/A I
inspect 25 but no other action for tubes in each is C 3 C 2 result of other SG.
second Notification to NRC Additional $G Inspect at t pursuant to is C 3 tubes in each N/A N/A 10CfR50.72
$G and plug defectives.
tubes Notification to NRC pursuant to 10CFR50.72.
S - 3 N/n % Where N is the number of SGs in the unit and n is the number of SGs inspected during inspection period.
(continued)
SAN ON0FRE--UNIT 3 5.0-18 Amendment No, 116 J
Procedures, Programs, and Manuals 3
j 5.5 5
5.5 Procedures Programs, and Manuals 1
5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) 5.5.2.11.1 The inservice inspection may be limited to one SG on a rotating schedule encompassing 6% of the tubes if the results
)
of the first or previous inspections indicate that all SGs are
]
performing in a like manner. Nate that under some circumstances, the operating conditions in one SG may be found a
i to be more severe than those in the other SG. Under such circumstances the sample sequence shall be modified to inspect the most severe conditionc.
5.5.2.11.2 The other SG not inspected during the first inservice inspection shall be inspected.
The third and subsequent inspections should follow the instructions described in i
Specification 5.5.2.11.1 above.
l 5.5.2.12 Ventilation Filter Testing Program (VFTP)
This Program establishes the required testing of the Engineered i
Safety Feature filter ventilation systems, " Control Room Emergency i
Air Cleanup System" and " Fuel Handling Building Post-accident 1
Cleanup filter System " in accordance with Regulatory Guide 1.52, i
Revision 2, and ASME N510-1989.
The frequency of testing shall be i
in accordance with Regulatory Guide 1.52, Revision 2.
As a minimum j
the VFTP program shall include the following:
j a.
Inplace testing of the high efficiency particulate air (HEPA) filters to deconstrate acceptable penetration and system i
bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME l
N510-1989; and 1
b.
Inplace testing of the charcoal adsorber to demonstrate acceptable penetration and system bypass tihen-tested at the j
appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989; and 4
i c.
Laboratory testing of charcoal adsorSer samples obtained in j
accordance with Regulatory Guide 1.52, Revision 2 and tested j
at the appropriate temperature and relative humidity in accordance with ASTM D3803 1989 to show acceptable methyl iodide penetration; and d.
Testing to demonstrate the pressure drua across the combined HEPA filters, the prefilters, and the clarcoal adsorbers, when tested at the appropriate system flowrate, is acceptable in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989.
2 (continued) i SAN ON0FRE--UNIT 3 5.0 19 Amendment No. 116 i
- - -.-~-
Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Special Reports Special Reports may be required covering inspection, test, and maintenance activities. These special reports are determined on an individual basis for each unit and their preparation and submittal are designated in the Technical Specifications.
Special Reports shall be submitted to the U. S. Nuclear Regulatory Conrnission, Attention: Document Control Desk, Washington, D. C.
20555, with a copy to the Regional Administrator of the Regional Office of the NRC, in accordance with 10 CFR 50.4 within the time period specified for each report.
The following Special Reports shall be submitted:
a.
When a pre-planned alternate method of monitoring post-accident instrumentation functions is required by Condition 8 or Condition H of LCO 3.3.11, a report shall be submitted within 30 days from the time the action is required.
The report shall outline the action taken, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the function to OPERABLE status, b.
Any abnormal degradation of the containment structure detected l
during the tests required by the Pre-Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days.
The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken, Following each inservice inspection of steam generator (SG) c.
tubes, in accordance with the SG Tube Surveillance Program, the number of tubes plugged and tubes sleeved in each SG shall be reported to the NRC within 15 days.
The com)1ete results of the SG tube inservice inspection shall be su)mitted to the NRC within 12 months following the completion of the inspection.
The report shall include:
1.
Number and extent of tubes inspected, and 2.
Location and percent of wall-thickness penetration for each indication of an imperfection, and 3.
Identification of tubes plugged and tubes sleeved.
(continued)
SAN ON0FRE--UNIT 3 5.0-30 Amendment No. 116
1 NPF-10/15 487 l
l I
i 1
1 ATTACHMENT C (Proposed Specifications)
Unit 2
RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYS1EM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:
a.
No pressure boundary LEAKAGE; b.
I gpm unidentified LEAKAGE; c.
10 gpm identified LEAKAGE; NOTE: ~ With no'SG sleeving' installed..-d. and'e. apply.
following installation of any sleeving in any SG' di and e do not_ apply and f. does apply.
d.
I gpm total primary to secondary LEAKAGE through all steam generators (SGs); and 720 gallons per day (1/2 gpm) primary to secondary e.
LEAKAGE through any one SG.
f.
~ With' steam generator' sleeving' installed in any SG, 150 gallons per day primary to secondary LEAKAGE through g
~
APPLICABILITY:
MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
RCS LEAKAGE not within A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limits for reasons within limits.
cther than pressure boundary LEAKAGE.
B.
Required Action and B.1 Be in MODE 3.
6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A 8@
not met.
B.2 Be in MODE S.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> M
Pressure boundary LEAKAGE exists.
SAN ON0FRE--UNIT 2 3.4-37 Amendment Wo. 127 L
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only).
The program shall include the following:
Preventive maintenance and periodic visual inspection a.
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 i
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 Testing Program This program provides controls for inservice testii,9 of ASME Code Class 1, 2, and 3 components including applicable supports.
Program itself is relocated to the LCS.
5.5.2.11 Steam Generator (SG) Tube Surveillance Program This program provides controls for monitoring SG tubo degradation.
Each SG shall be demonstrated OPERABLE by meeting the requirements of Specification 5.5.2.11 and by meeting an augmented inservice inspection Revision 1, program based on a modification of Regulatory Guide 1.83, 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 Tables 5.5.2.11-1 and 5.5.2.11 2.
l b.
SG Tube Sample Selection and Inspection The SG tube and; sleeve minimum sample size, inspection result l
classification, and the corresponding action required shall be as specified in Tables 5.5.2.11 1 and-5.5.2.ll-2.
The inservice ins)ection~of SG tubes and sleeves :shall be performed at tie frequencies specified in Specification 5.5.2.11.e and the inspected tt.bes shall be verified acceptable per the acceptanco criteria of Specification 5.5.2.il.f.
The tubes selected for each inservice inspection shall include at least 3'4 of the total (continued)
SAN ON0FRE--UNIT 2 5.0-13 Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) number of tubes in all SGsl the tubes selected for these inspections shall be selected on a random basis except:
i 1.
Where experience in similar plants with similar water chemistry indicates critical areas to be inspected, then at least 50% of the tubes inspected shall be from the critical areas; 2.
The first sample of tubes selected for each inservice i
ins)ection (subsequent to the preservice inspection) of eac1 SG shall include:
a)
All nonphgg:dnon; repaired tubes.that previously
)
had detectable wall penetrations (greater than 20%),
b)
Tubes in those areas where experience has indicated potential problems, and c)
A tube inspection (pursuant to Specification 5.5.2.ll.f) shall be performed on each selected tube.
If any selected tube does not permit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection.
3; All sleeves shall"be inspected with*eady current' prior
~to initial operation. This. includes pressure retaining portions of the.parentxtube'in contact with the sleeve 4 the ' sleeve to-tube' weld and" the pressure. r,etaining portion of the sleeve.
.4 '.
Following'the"preservice inspection,L. 20%~of sleeverthat have been in service-for: a full cycle of operation!shall be11nspected.- The sleeves shall be'.selectedLon a random basis ~. -If indications of degradation are found in the sample the inspection sample-shall"be' expanded.. Table 5.5.2.11-2 contains the requirements for samp1f expansion.:
(continued)
SAN ON0FRE--UNIT ?
5.0-14 Amendment No. 127
Procedures, rograms, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Eteam Generator (SG) Tube Surveillance Program (continued) c.
Examination Results The results of each sample inspection shall be classified into one of the following three categories:
i C-1 Less than 5% or the total tubes inspected are degraded l
tubes and none of the inspected tubes are defectivo.
C2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.
C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.
This classification shall also apply to sample inspections _of sleeves.
............................N0TE-In all inspections, previously degraded non re aireditubes must exhibit significant (greater than 10%)~fu ther wall penetrations to be included in the above percentage calculations.
d.
Supplemental Sampling Requirements The tubes selected as the second and third samples (if required by Table 5.5.2.11 1) may be subjected to a partial tube inspection provided:
1.
The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfection: were previously found, and 2.
The inspections include those portions of the tubes where imperfections were previously found.
(continued)
SAN ONOFRE--UNIT 2 5.0 15 Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedure:, Programs, and Manuals 5.5.2.11 Steam Generator (50) Tube St.rveillance Program (continued) e:
Inspection frequency The above requireu inservice ins)ections of the non repaired SG tubes shall be performed at tie following frequencies:
1.
TM f M t sny rvice inspection shall be performed after 6 eff ecthe full power months but within 24 calendar l
months of initial critically.
Subsequent ir:,ervice i
inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection.
If two consecutive inspections, not including the preservice inspection, result in all inspections results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no add..ional degradation has_ occurred, the inspection interval may be extended to 4 maximum of once per 40 monthsr 2.
If the results of the inservice inspection of a SG conducted in accordance with Table 5.5.2.11-1 at 40-month intervals fall in Category C-3, the inspection shall be increased to at least once per 20 months. The increasc in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.2.ll.fe;1, the interval may then be extended to a maximum of once per 40 months; and 3.
Additional, unscheduled inservice inspections shall be performed on each SG in accordance with the first sample inspection specified in Table 5.5.2.11-1 during the shutdown subsequent to any of the following conditions:
a)
Primary-to secondary tubes leak (not including leaks originating from tube-to tube sheet welds) in excess of the limits of Technical Specification 3.4.13, or b)
A seismic occurrence gre,ter than the Operating Basis Earthquake, or c)
A loss-of-coolant accident requiring actuation of the Engineered Safety Features, or d)
A main steam-line or feedwater line break.
(continued)
SAN ON0FRE-UNIT 2 5.0-16 Amendment No. 127
Procedures Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 SteamGenerator(SG)TubeSurveillanceProgram (continutd) 4.
The provisions of Technical S)ecifications Surveillance Requirement 3.0.2 are applica)1e to SG Tube Surveillance inspection frequencies except those established by Category C 3 inspection results.
The=abovp required inservice" inspections of SG tubes = repaired by sleeving shall be performed at the following, frequencies:
l l '. -
' Steam generator tube'sleevestshall be; inspected prior _~ to initial operation and-in service.,The~ initial operating period before the' initial-inservice:sampletinspection shall not be shorter than six months nor longer thanL24 months.. The inspections'of; sleeves shall be configured to ensure that=each individual sleeve is inspected at ~
least.oncelin 60 months; 2.P 'If the results^ nf:the~ inserviceTinspectton of SG tisbe sleeves conducted;in:accordance-with-Table 5.5.2.11 2 fall'in category, C-3,1 the inspection frequency shall be increased to ensure that each remaining sleeve is inspected at least once in'30 months. -The _ increase in inspection frequency shallrapply until:the subsequent'
. inspections satisfy the-criteria-for_ Category;C-1.-
f.
Acceptance Criteria l.
Terms as used in this specification will be defined as follows:
a)
Degradation - A service-induced cracking, wastage, wear, or general-corrosion occurring on either inside or outside of a tube; b)
Degraded tube - A tube containing imperfections greater than or equal to 20% of the nominal wall thickness cause by degradation; c)
% Degradation - The percentage of the tube wall thickness affected or removed by degradation; d)
Defect - An imperfection of such severity nat it exceeds the pkgghg-repair limit. A: tube containing a defect is'defectivet' (continued)
SAN ON0FRE-UNIT 2 5.0 17 Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) e)
Imperfectior.
An exception to the dimensions, finish, or contour of a tube from that required by i
fabrication drawings or specifications.
Eddy-current testing indications below 20% of the _
nominal tube wall thickness, if detectable, may be considered as imperfections; f)
Phytt%<f-Repair-l.imit The imperfection depth at or beyond which the tube shall be removed from service or repaired and is equal to 44% of the nominal tube wall thickness; Sleeves shall be removed'from= service upon' detection of service-induced degradation of the sleeve material or_ any portion.of the sleeve to tube weld.
_g)
Preservice inspection - An inspection of the full length of each tube in each SG performed by eddy-current techniques prior to service to establish a baseline condition of the tubing.
This inspection shall be performed prior to initial MODE 1 operating using the equipment and techniques expected to be used during subsequent inservice inspections.
These examinations may be performed prior to steam generator installation.
Similarly, for: tube repair by sleeving,~ an inspection of-the full: length of the pressure boundary portion of the sleeved area-shall-be performed by eddy current techniques prior to-service. This~
includes pressure retaining _ portions of the-parent tube in contact with the sleeve,'the' sleeve-to-tube weld, and the, pressure retaining portionLof the sleeve; h)
Tube Inspection - An inspection of the SG tube from the point of entry (hot leg side) completely around the U-bend to the top support of the cold leg; and i)
Unserviceable - The condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operational Basis Earthquake, a loss-of-coolant accident, or a steam line of feedwater line break accident as specified in Specification 5.5.2.ll.e.
(continued)
SAN ON0FRE--UNIT 2 5.0-18 Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals i
5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) j)
Tube Repair - refers to a process that reestablishes tube serviceability. A:ceptable tube repairs will' be performed by the following process:
TIG welded sleeving as described in ABB/CE Topical Report, CEN-630 P, Rev. 2, is currently approved by the NRC.
)
Tube repair includes the installation by welding of the sleeves, heat treatment in accordance with CEN 630-P, Rev. 2, to remove the stresses that are introduced by the sleeve installation, acceptance testing of the sleeve, and nondestructive examination for future comparison. Tube repair can be performed on certain tubes that have been previously plugged as a corrective or preventive measure.
A tube inspection of the full length of the tube shall be performed on a 3reviously plugged tube prior to returning tie tube to service.
2.
The SG shall be determined OPERABLE after completing the corresponding actions (plug or repair all 'ubes exceeding the p4ugg4n9-repair limit and all tubes containing through-wall cracks, and plug all sleeved tubes'that exceed the repair criteria) required by Tables 5.5.2.ll-1: and 5.5.2.11-2.
g.
Reports The content and frequency of written reports shall be in accordance with Technical Specification 5.7.2, "Special Reports."
(continued)
SAN ON0FRE--UNIT 2 5.0-19 Amendment No. 127
Procedures, Programs, and Manuals j
5.5 i
l!
5.5 Procedures, Programs, and Manuals j
5.5.2.11 Steam Generator Tube Surveillance Program 4
TABLE 5.5.2.11 1 (page 1 of 1)
STEAM GENERATOR TVBE INSPECTION j
SUPPLEMENTAL SAMPLING REQUIREMENTS j
ist sagte inspection 2nd Sample Inspection 3rd Sagle inspection i
Action Actic.n Action tavle $lte Result Required Result Required Result Required i
A minisun of C*1 None N/A N/A N/A N/A t
i g
C+2 Plug tr'repalt C1 None N/A N/A w su.ving l'
oefective tubes Plug br repolt h N/A N/A and inspect an klooVIhl l
additional 296 defective t W es C+1 N/A l
{@*esinthis t
an Cal Pig w W tubes in this $G.
W abing 4
j defective t ees.
C3 Perfore action t
for C J result i
of first j
serpte.
I C3 Perform action N/A N/A for C 3 result of j
first sanple.
i i
C3 Inspect all Att other hone N/A N/A tubes in this
$Gs C 1 j
$G plug or i
repair W f
some SGs C 2 Perform action N/A N/A t e tubes j
and inspect 2$
but no other for C 2 result of tubes a each is C 3 second sanple.
I other $G.
i 1
Additional Inspect all tubes N/A N/A Notification to SG is C 3 in each $0 and NRC pursuant to plugorrepalr.W IOCFR50.72 eteevIng l
defective tubes.
Notification to
}
NRC pursuant to t0CFR50.72.
,]
S.= 3 N/n % Where N is the number of SGs in the unit and n is the number of 1
i SGs inspected during inspection period.
i i
i i
f (continued) 4 i
SAN ONOFRE -UNIT 2 5.0-19a Amendment No. 127 J
i
. - -... ~...
. - _.. _. - _ _ _ _ _ _ _, _. _ - - - ~. _ _,. -... -. _. - - - - -.. _.
.....,.m.___-,
Procedures Programs, and Manuals 5.5 5.5 Procedures Programs, and Manuals Table 5.5.2.11-2 (page 1 of 1)
Steam Generator Sleeved Tube Inspection 1st Sample Inspection 2nd Sample Inspection Sample Site Result Action Required Result Action Required C-1 None N.A.
N.A.
l Plug defective C-1 None repaired tubes and inspect Plug defective, 100%.of the C,2 repaired tubes.
C-2 sleeves in this SG Perform action f r C 3 result C-3 of first sample.
Inspect all
{'P Other SG is C-1 None n
S A minimum of plug defective 20% of the repaired tubes, and inspect 20%
Perform action fter hr resuh Vs Other SG in C-2
{
SG.
sampic.
[
C-3 Notification to Inspect all NRC pursuant to repaired tubes 50.72 (b)(2) of in both SG's 10CFR Part 50 and plug defectivo Other'SG is C-3 repaired tubes.
Notification to NRC pursuant to 50.72 (b)(2) of 10CFR Part 50 (continued)
SAN ON0FRE--UNIT 2 5.0-19b Amendment No. 127
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) 5.5.2.11.1 1he inservice inspection may be limited to one SG on a rotating schedule encompassing 6% of the tubes if the results of the first or t
previous inspections indicate that all SGs are performing in a like manner. Note that under some circumstances, the operating I
conditions in one SG may be found to be more severe than those in the other SG.
Under such circumstances the sample sequence shall be modified to inspect the most severe conditions.
5.5.2.11.2 The other SG not inspected during the first inservice inspection shall be inspected. The third and subsequent inspections should follow the instructions described in Specification 5.5.2.11.1 above.
5.5.2.12 Ventilation Filter Testing Program (VFTP)
This Program establishes the required testing of the Engineered Safety Feature filter ventilation systems, " Control Room Emergency Air Cleanup System" and " Fuel Handling Building Post-accident Cleanup Filter System," in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510 1989.
The frequency of testing shall be in accordance with Regulatory Guide 1.52. Revision 2.
As a minimum the VFTP program shall include the following:
Inplace testing of the high efficiency particulate air (HEPA) a.
filters to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revistoa 2, ano ASME H510 1989; and b.
Inplace testing of the charcoal adsorber to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989; and Laboratory testing of charcoal adsorber samples obtained in c.
accordance with Regulatory Guide 1.52, Revision 2 and tested at the appropriate temperature and relative humidity in accordance with ASTM D3803 1989 to show acceptable methyl iodide penetration; and d.
Testing to demonstrate the pressure dro) across the combined HEPA filters, the prefilters, and the clarcoal adsorbers, when tested at the appropriate system flowrate, is acceptable in accordance with Regulatory Guide 1.52, Revision 2, and ASME H510-1989.
(continued)
SAN ON0FRE-UNIT 2 5.0-19c Amendment No. 127
Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Soecial Reports Special Reports may be required covering inspection, tett, and maintenance activities.
These special reports are determined on an individual basis for each unit and their preparation and submittal are designated in the Technical Specifications.
Special Reports shall be submitted to the U. S. Nuclear Regulatory l
Commission Attention: Document Control Desk, Washington, D. C.
20555, with a copy to the Regional Administrator of the Regional Office of the NRC, in accordance with 10 CFR 50.4 within the time I
period specified for each report.
The following Special Reports shall bo submitted:
When a pre planned alternate method of monitoring post-a.
accident instrumentation functions is required by Condition B or Condition H of LCO 3.3.11, a report shall be submitted within 30 days from the time the actior is required.
The report shall outline the action taken, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the function to OPERABLE status, b.
Any abnormal degradation of the containment structure detected during the tests required by the Pre Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken.
Following each inservice inspection of steam generator (SG) c.
tubes, in accordance with the SG Tube Surveillinee Program, the number of= tubes plugged and tubes sleeved in each SG shall be reported to the NRC within 15 days.
The coiolete results of the SG tube inservice inspection shall be submitted to the NRC within 12 months following the completion of the inspection.
The report shall include:
1.
Number and extent of tubes and'sleevesiinspected, and 2.
Location and percent of wall-thickness penetration for each indication of an imperfection, and 3.
Identification of tubes plugged and tubes sleeved.
(continued)
SAN ONOFRE--UNIT 2 5,0-30 Amendment No. 127
NPf 10/15 487 l
4 ATTACHMENT D (Proposed Specifications)
Unit 3
RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE i
LC0 3.4.13 RCS operational LEAKAGE shall be limited to:
j a.
No pressure boundary LEAKAGE; P
j b.
I gpm unidentified LEAKAGE; i
i c.
10 gpm identified LEAKAGE; i
i NOTE;i ; Wi th ? n6f SG f sl eevi ng?in s tal led;f d u and ? e;(ap'plys?
~ ~ ^ Following tinstallation of: anyisleevingiinf any"l SGi"f d.$
and?.e,;.do?notapply[and#does(applyf
~ '"
d.
I gpm total primary to secondary LEAKAGE through all steam j
generators (SGs); and 3
e.
720 gallons per day (1/2 gpm) primary to secondary LEAKAGE a
through any one SG.
ff JWithisteam generato~r sleevinglinstalledTinTa~nfiSG;
~')50lga_llons;peridayiptiparyitojeco)dariiLEAKAGE(throygh anyjoneS03 APPLICABILITY:
MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
RCS LEAKAGE not within A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limits for reasons within limits.
other than pressure boundary LEAKAGE.
B.
Required Action and B.1 Be in MODE 3.
6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A AND not met.
B.2 Be in MODE 5.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> 08 Pressure boundary LEAKAGE exists.
1 SAN ON0FRE--UNIT 3 3.4-37 Amendment No. 116 m-W m
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only). The program shall include the following:
Preventive maintenance and periodic visual inspection a.
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 Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports.
itself is relocated to the LCS.
Program 5.5.2.11 Steam Generator (SG) Tube Surveillance Program This program provides controls for monitoring SG tube degradat hn.
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:
i SG Sample-Selection-and Inspection a.
Each SG shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum number of SG specified in Tables 5.5.2.ll-1;and 5.5.2;11-2.
b.
SG Tube Sample Selection and Inspection The SG tube andtsleevel minimum sample size, inspection result classification,'and the corresponding action required shall be l
as specified in Tables 5.5.2.ll-15and 5;5.-2;11'-2.
The inservice ins)ection' of SG tubes' and sleeves:shall be performed at tie frequencies specified in Specification 5.5.2.ll.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 inspection shall include at least 3% of the total (continued)
SAN ON0FRE--UNIT 3 5.0-13 Amendment No. 116
Procedures, Programs, and Manuals 5.5 5.5 Proceduros, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube-Surveillance Program (continued) number of tubes in all SGs; the tubes selected for these inspections shall be selected on a random basis except:
1.
Where experience in similar plants with similar water chemistry indicates critical areas to be inspecteel then at least 507, of the tubes inspected shall be fror
.e critical areas; 2.
The first sample of tubes selected for each inservice ins)ection (subsequent to the preservice inspection) of eac1 SG shall include:
a)
All ncnph;;cd non? repaired tubes that previously had detectable kall" penetrations (greater than 207.),
b)
Tubes in those areas where experience has indicated potential problems, and c)
A tube inspection (pursuant to Specification 5.5.2.ll.f) shall be performed on each selected tube.
If any selected tube does not. permit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection.
3R" (~ MITileevesishalls beEihspectedfwithieddfic6truntTprior
~'
tolinitialEoperationrAThisnincludesfpressuretretai port i on s Lo fx the f pare nti tube % i ni cont act[wi thit he1sl en eveg the1 sleeve +tostube weldLand?the!p"ressure! retaining portion (offthejsl.eeve?
' ~ ~ ' ~~ ~
.4M JFoll6wthgythfiprehirVicei,inspectidnM20W6fGleeves5that gf fg j
p
)
be11nsoectedbTheisleevestshall beiselectedfonta' random basis 91ffindic'ati'nslofNegradation>/ireifoundlisitheT-o s ampl eithe s i n s pect i on s s ampl e : sh al li beTexp anded WTabl e 5;5:2;11s2{containsithe requirementsyforlsampls ~ ""
expansione (continued)
SAN ONOFRE--UNIT 3 5.0-14 Amendment No. 116
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) c.
Examination Results The results of each sample inspection shall be classified into one of the following three categories:
C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective.
C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.
C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.
Th i s ;cl a s s i fi cati on 'sha11 ? al solappl yitofs ampl e'li n spect,1,onslof sleev,esy
...........................-N0TE--------------------------
In all inspections, previously degraded non!repaireditubes must exhibit significant (greater than 10%)"further Wall penetrations to be included in the above percentage calculations.
d.
Supplemental Sampling Requirements The tubes selected-as the second and third samples (if required by Table 5.5.2.11-1) may be subjected to a partial tube inspection provided:
1.
The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfections were previously found, and 2.
The inspections include those portions of the tubes where imperfections were previously found.
(continued)
SAN ON0FRE--UNIT 3 5.0-15 Amendment No, 116
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) e.
Inspection Frequency l
The above required inservice ins)ections of the nonfrepaired SG tubes shall be performed at tie follow:ng fregisencle'si"^
1.
The first inservice inspection shall be performed after 6 effective full power months but within 24 calendar months of initial critically.
Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection.
If two consecutive inspections, not including the preservice inspection, result in all inspections results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additiona; degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months; 2.
If the results of the inservice inspection of a SG l
conducted in accordance with Table 5.5.2.11-1 at 40-I month intervals fall in Category C-3, the inspection shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.2.ll. fell, the interval may then be extended to a maximum of"once per 40 months; and 3.
Additional, unscheduled inservice inspections shall be performed on each SG in accordance with the first sample inspection specified in Table 5.5.2.11-1 during the shutdown subsequent to any of the following conditions:
a)
Primary-to-secondary tubes leak (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of Technical Specification 3.4.13, or b)
A seismic occurrence greater than the Operating Basis Earthquake, or c)
A loss-of-coolant accident requiring actuation of the Engineered Safety Features, or d)
A main steam line or feedwater line break.
(continued)
SAN ON0FRE--UNIT 3 5.0-16 Amendment No. 116
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) 4.
The provisions of Technical Specifications Surveillance Requirement 3.0.2 are applicable to SG Tube Surveillance inspection frequencies except those established by Category C-3 inspection results.
The.~above7 required; inservice ~1nspedtionsofSGitubesi:'repairedbf sleevingshallibelperformedatithe:following(frequencies:
4 1.~
ES te am' "ge ne rat o r ; tube ~s.l eeve s i sh a11 :l be'11ln s pec t ed " pri o r; to
' initial: operation:and in" service.n Therinttialsoperating i
period? before ithelinitial Kinservice Tsampleiinspection~~
shall not be:: shorter thanisix monthsinorilonger! than}24 4
inonths'. :jTheXinspections:of;sleevesishallt beiconfigured toLensurethatreach31ndividualssleevefisfinspected(at" l
least:oncefinj60 monthst l
- 2. 2 JIfithe';resultsTof: the~1nserVice3 f nspectiont ofisGitube
~~ ^ ^ leevesJconductedLinJaccordance with:Tablei5.5.2211-2 s
4 f al if i n i ck tegory'; CL3,it he k i nspect i oni: frequfncy ishall s be increased;toensureithatleachiremainingislee'vesis
~~
inspectediatsleast:oncelint30fmonths O The increas'e H n 3
inspection:frequencyishallf apply untilhthe / subsequent ~
j inspectionsisatisfyfthe criterialforJCategorylC-It "
3 f.
Acceptance Criteria i
1.
Terms as used in this specification will be defined as follows:
) --
a)
Degradation - A service-induced cracking, wastage, wear, or general corrosion occurring on either inside or outside of a tube; I
t b)
Degraded tube - A tube containing imperfections j
greater than or equal to 20% of the nominal wall thickness cause by degradation;-
c)
% Degradation - The percentage of the tube wall thickness affected or removed by degradation; d)
Defect - An imperfection of such severity that it exceeds the plugging repair limit. A tube containing a defect is'defectiveti (continued)
SAN ON0FRE--UNIT 3 5.0-17 Amendment No, 116
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals l
5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) e)
Imperfection - An exception to the dimensions, finish, or contour of a tube from that required by fabrication drawings or specifications.
Eddy-current testing indications below 20% of the nominal tube wall thickness, if detectable, may be considered as imperfections; f)
A ggingRepair Limit - The imperfection depth at l
I or beyond which the tube shall be removed from service or'repairediand is equal to 44% of the nominal tube ^ wall thickness; SleevesishallTbs removed 7 from'servicefup6n^ detection offservice?
i_ nduced Jdegradationto f, t hei sl eevelmaterialL oriani po rt.i o n) o f;the :l sl eeve -to; tube i wel d t g)
Preservice Inspection - An inspection of the full length of each tube in each SG performed by eddy-current techniques prior to service to establish a baseline condition of the tubing.
This inspection shall be performed prior to initial MODE 1 operating using the equipment and techniques expected to be used during subsequent inservice inspections. These examinations may be performed prior to steam generator installation.FSimilarly?
for"tubeTrepair by?sleevi'ngMan!inspectloniof Cthe"'
full 11ength of;the': pressure boundary' portion of-'
the? sleeved 1 area 'shall: be performed;byfeddy"
burrentftechniquesfpriorftotserviced':tThis i...
includes'pressureEretaining portiss(of!the; parent tube inkontact withithetsleevedthe) sleeve-tof '
tube; weld,::and_thelpressurejretaiginglportionTof thersleeve h)
Tube Inspection - An inspection of the SG tube from the point of entry (hot leg side) completely around the U-bend to the top support of the cold leg; and i)
Unserviceable - The condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operational Basis Earthquake, a loss-of-coolant accident, or a steam line of feedwater line break accident as specified in Specification 5.5.2.ll.e.
(continued)
SAN ON0TRE--UNIT 3 5.0-18 Amendment No. 116
1 Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) j)"
- Tube Repair M refers to aTprocess'that
' reestablishes tube serviceability. Acceptable tube; repairs,will be performed by the following pyrocess:
TIGNelded sleeving' as described!in; ABB/CE Topical Report, CEN-630-P, Rev.1 2,-is currently approved by the.NRC.,
~~
~
~
Tube repair" includes the' installation by welding of the' sleeves, heat treatment.in'accordance with CEN-630-P, Rev. 2,-to remove *the stresses that.are introduced by'the= sleeve installation,- acce testing of the sleeve, andi nondestructive 'ptance~
examination foi future' comparison. 1 Tube: repair can be performed on certain tubes-that:have been previously plugged as a corrective or-preventive measure. --A. tube inspection oflthe; full length _of the tube'shall;be-performea on,a previously ~ ~
plugged tube _ prior toireturning the' tube.to service.
2.
The SG shall be determined OPERABLE after completing the corresponding actions (plug or repairJall tubes-exceeding-the phgging repair'~ limit' ~and all tubes -
containing through-wall cra'cks, and plug lall sleeved tubes:that= exceed'theirepair" criteria)^ required'by~~
Tables 5. 5 ; 2.11:1! a'nd ; 5. 5.2.11-2 ~
~
g.
Reports The content and frequency of written reports shall be in accordance with-Technical Specification 5.7.2, "Special Reports."
(continued)
SAN ON0FRE--UNIT 3 5.0-19 Amendment No. 116
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals 5.5.2.11 Steam Generator Tube Surveillance Program TABLE 5.5.2.11-1 (page 1 of 1) l STEAM GENERATOR TVBE INSPECTION SUPPLEMENTAL SAMPLING REQUIREMENTS ist Samle Inspection 2nd Sa mte Inspection 3rd Sample inspection Action Action Action Sa wte Site Result Required Result Required Result Required A mininun of C1 None N/A N/A N/A N/A S tubes per SG C2 Plug or repair C1 None N/A N/A by sleeving defective tubes Plugorrepairjby N/A N/A and inspect an sleeving additional 2$5 defoctive tubes C1 N/A e in this and s t
an C2 Plug or repair tubes in this SG.
s ng f,
tubes.
C3 Perform action for C 3 result of first sample.
C3 Perform action N/A N/A for C-3 result of first sagte.
C3 Inspect att Att other None N/A N/A tubes in this SGs C-1 SG plug or repair by S me SGs C 2 Perform action N/A N/A e tubes but no other for C 2 result of and inspect 25 tubes in each is C-3 second sample.
other SG.
Additional Inspect att tubes N/A N/A Notification to SG is C 3 in each SG and NRC pJFsuant to plug orIrepaIP.by 10CFR50.72 sleeving ~
~
defective tubes.
Notification to NRC pursuant to 10CFR50.72.
S - 3 N/n % Where N is the number of SGs in the unit and n is the number of SGs inspected during inspection period.
I (continued)
SAN ON0FRE--UNIT 3 5.0-19a Amendment No, 116
Procedures, Programs, and Manuals 5.5 1
5.5 Procedures, Programs, and Manuals Table 5.5.2.11-2 ' ( > age -1 of 1)
Steam Generator Sleevec Tube Inspection 1st Sample Inspection 2nd Sample Inspection Sample ;Si:e Result Action Required Result Action Required C-1 None N.A.
N. A.'
Plug defective C-1 None repaired tubes and inspect Plug defectives 100% of the C-2 repaired tubes.'
~
Perform action for.C-3 result C-3 of first sample.
' Inspect all repaired tubes in this SG, Other.SG is C-1 None A minimum of plug defective 20% of repaired tubes,~
- sleeves, and inspect 20%
Perform action of the sleeves ~
for C-2 result Other SG is C-2 in the other of:first' i
SG.
sampl e.-
C-3 Notification to Inspect all i
NRC pursuant'to repaired tubes 50.72 (b)(2) of in both SG's 10CFR Part 50 and plug i
defective Other SG is'C-3 repaired tubes.
Notification to NRC pursuant _.to 50.72 (b)(2) of 10CFR Part 50 (continued)
SAN ON0FRE--UNIT 3 5.0-19b Amendment No. 116
Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals i
5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) 5.5.2.11.1 The inservice inspection may be limited to one SG on a rotating schedule encompassing 6% of the tubes if the results of the-first or previous inspections indicate that all SGs are performing in a like manner.
Note that under some circumstances, the operating conditions in one SG may be found to be more severe than those in the other SG. Under such circumstances the sample sequence shall be modified to inspect the most severe conditions.
5.5.2.11.2 The other SG not inspected during the first inservice inspection shall be inspected.
The third and subsequent inspections should follow the instructions described in Specification 5.5.2.11.1 above.
5.5.2.12 Ventilation Filter Testing Program (VFTP)
This Program establishes the required testing of the Engineered Safety Feature filter ventilation systems, " Control Room Emergency Air Cleanup System" and " Fuel Handling Building Post-sccident Cleanup Filter System," in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989.
The frequency of testing shall be in accordance with Regulatory Guide 1.52, Revision 2.
As a minimum the VFTP program shall include the following:
a.
Inplace testing of the high efficiency particulate air (HEPA) filters to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989; and b.
Inplace testing of the charcoal adsorber to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989; and c.
Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested at the appropriate temperature and relative humidity in accordance with ASTM D3803-1989 to show acceptable methyl iodide penetration; and d.
Testing to demonstrate the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers, when tested at the appropriate system flowrate, is acceptable in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989.
(continued)
SAN ON0FRE--UNIT 3 5.0-19c Amendment No. 116
Reporting Requirements 5.' 7 5.7 Reporting Requirements (continued) 5.7.2 Soecial Reoorts Special Reports may be required covering inspection, test, and maintenance activities.
These special reports are determined on an individual basis for each unit and their preparation and submittal are designated in the Technical Specifications.
Special Reports shall be submitted to the U. S. Nuclear Regulatory Commission, Attention: Document Control Desk, Washington, D. C.
20555, with a copy to the Regional Administrator of the Regional Office of the NRC, in accordance with 10 CFR 50.4 within the time period specified for each report.
The following Special Reports shall be submitted:
a.
When a pre-planned alternate method of monitoring post-accident instrumentation functions is required by Condition B or Condition H of LC0 3.3.11, a report shall be submitted within 30 days from the time the action is required.
The report shall outline the action taken, the cause of the inoperability, and the plans and senedule for restoring the instrumentation channels of the function to OPERABLE status, b.
Any abnormal degradation of the containment structure detected t
during the tests required by the Pre-Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days.
The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken, Following each inservice inspection of steam generator (SG) c.
tubes, in accordance with the SG Tube Surveillance Program, the number of tubes plugged and tubes sleeved in each SG shall be reported to the NRC within 15 days.
The complete results of the SG tube inservice inspection shall be submitted to the NRC within 12 months following the completion of the inspection. The report shall include:
1.
Number and extent of tubes and[sleansjinspected, and 2.
Location and percent of wall-thickness penetration for each indication of an imperfection, and 3.
Identification of tubes plugged and tubes sleeved.
(continued)
SAN ON0FRE--UNIT 3 5.0-30 Amendment No, 116
ENCLOSURE 2 PROPOSED BASES SAN ONOFRE UNITS 2 AND 3
s 4
f (ProposedBASESPage)
Unit 2
RCS Operational LEAKAGE B 3.4.13 8 3.4 REACTOR COOLANT SYSTEM (RCS)-
B 3.4.13 RCS Operational LEAKAGE BASES BACKGROUND Components that contain or transport the coolant to or from the reactor core make up the RCS.
Component joints are made by welding, bolting, rolling, or pressure loading, and
-valves isolate connecting systems from the RCS.
i During plant life, the joint and valve interfaces can produce varying amounts of reactor coolant LEAKAGE, through either normal operational wear or mechanical deterioration.
The purpose of the RCS Operational LEAKAGE LC0 is to limit system operation in the presence of LEAKAGE from these sources to amounts that do not compromise safety. This LC0 specifies the types and amounts of LEAKAGE.
10 CFR 50, Appendix A, GDC 30 (Ref. 1), requires means for detecting and, to the extent practical, identifying the 4
source of reactor coolant. LEAKAGE.
Regulatory Guide 1.45 (Ref. 2) describes acceptable methods for selecting leakage detection systems.
The safety significance of RCS LEAKAGE varies widely depending on its source, rate, and duration.
Therefore, detecting and monitoring reactor coolant LEAKAGE into the i
containment area is necessary. Quickly separating the identified LEAKAGE from the unidentified LEAKAGE is necessary to provide quantitative information to the i
operators, allowing them to take corrective action should a leak occur detrimental to the safety of the facility mnd the public.
A limited amount of leakage inside containment is expected from auxiliary systems that cannot be made 100% leaktight.
Leakage from these systems should be detected, located, and isolated from the containment atmosphere, if possible, to not interfere with RCS LEAKAGE detection.
This LCO deals with protection of the reactor coolant pressure boundary (RCPB) from degradation and the core from inadequate cooling, in addition to preventing the accident analysis radiation release assumptions from being exceeded.
The consequences of violating this LC0 include the possibility of a loss of coolant accident (LOCA).
(continued)
SAN ON0FRE--UNIT 2 B 3.4-70 Amendment No. 127
RCS Operational LEAKAGE B 3.4.13 BASES (continued)
APPLICABLE Except for primary to secondary LEAKAGE, the safety analyses SAFETY ANALYSES do not address operational LEAKAGE. Howevca, other operational LEAKAGE is related to the safm/ analyses for LOCA; the amount of leakage can affect the probability of such an event. The safety analysis for an event resulting in steam discharge to the atmosphere assumes a 1 gpm primary to secondary LEAKAGE as the initial condition.
Primary to secondary LEAKAGE is a factor in the dose releases outside containment resultina from a steam line break (SLB) accident.
To a lesser extent, other accidents or transients involve secondary steam release to the atmosphere, such as a steam generator tube rupture (SGTR).
The leakage contaminates the secondary fluid.
The UFSAR (Ref. 3) analysis for SGTR assumes the contaminated secondary fluid is only briefly released via safety valves and the majority is steamed to the condenser.
The 1 gpm primary to secondary LEAKAGE is relatively inconsequential.
The SLB is more limiting for site radiation releases. The safety analysis for the SLB accident assumes 1 gpm primary to secondary LEAKAGE in one generator as an initial condition.
The dose consequences resulting from the SLB accident are well within the limits defined in 10 CFR 50 or the staff approved licensing basis (i.e., a small fraction of these limits).
RCS operational LEAKAGE satisfies Criterion 2 of the NRC Policy Statement.
LC0 RCS operational LEAKAGE shall be limited to:
a.
Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material deterioration.
LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE.
Violation of this LC0 could result in continued degradation of the RCPB.
LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.
(continued)
SAN ON0FRE--UNIT 2 B 3.4-71 Amendment No. 127
RCS Operational LEAKAGE B 3.4.13
-BASES LC0 b.
Unidentified LEAKAGE (continued)
One gallon per minute (gpm) of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment air monitoring and containment sump level monitoring equipment can detect within a reasonable time period.
Violation of this LCO could result in continued degradation of the RCPB, if the LEAKAGE is from the pressure boundary, c.
Identified LEAKAGE Up to 10 gpm of identified LEAKAGE is considered allowable because LEAKAGE is from known sources that do not interf ere with detection of identified LEAKAGE l
and is well within the capability of the RCS makeup system.
Identified LEAKAGE includes LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal leakoff (a normal function not considered LEAKAGE).
Violation of this LC0 could result in continued degradation of a component or system.
LC0 3.4.14, "RCS Pressure Isolation Valve (PIV)
Leakage," measures leakage through each individual PIV and can impact this LCO.
Of the two PIVs in series in each isolated line, leakage measured through one PIV
{
does not result in RCS LEAKAGE when the other is leaktight.
If both valves leak and result in a loss of mass from the RCS, the loss must be included in the allowable identified LEAKAGE.
d.
Primary to Secondary LEA AGE throuah All Steam Generators (SGs)
Total primary to secondary LEAKAGE amounting to 1 gpm through all SGs produces acceptable offsite doses in the SLB accident analysis. Violation of this LC0 could exceed the offsite dose limits for this accident analysis. A ~ more' icon serva t i ve TLC 0f l im i t ?o f 6150 ! Gal l on s' '
perJ day 1(GPD)? through;each : steam;generat_d isteam ' 'orjis address 1steamigenerator?tubetsleevingran generator! tube degradationWThisilimituslimposed[oii bo th ;SGs d i n, Uni tJ 2 Lfol l owi ng (l icen s i ng tand Li ns t al l ati on
'ffalsteam(generatoritsbelslee_ vet,inietther;SGMThe'"
o (continued)
SAN ON0FRE--UNIT 2 B 3.4-72 Amendment No. 127
RCS Operational LEAKAGE B 3.4.13 BASES LCO-rel atichhi pibetWeen sl eakagCl imi t s'andi t ubal (continued) degradationf andlsleevinglisidiscussed;inithe Tfollowing
'sectionsf; 'Primarf to"sedondarf' LEAKAGE"must be"'
included"in the total allowable limit for identified LEAKAGE.
e.
Primary to Secondary LEAKAGE throuch Any One SG The 720 gallon per day limit on primary to secondary LEAKAGE through any one SG allocates the total 1 gpm allowed primary to secondary LEAKAGE equally between the two generators. AJ11mitTof throughcany onessteimigeneratore(1501GallonssperTday isnimposedlon:
22 9?ngtat3rg ube(sleevesi g " " - ""f ~ steam L
fol_ lowing 911cinsing and installationtof
" ~'
Q Q Steani%sneratoEftubsidsgradationTsschThilstre H corrosionferacking defects:may;occt;rsand;>ropag~ ate frontinside)ordfrom thefoutsideiofstheitu>es7
^^*
particularlilinitheiareasSwithinfthe7tubesheet7and immediatelyJabove?theitube' sheet O stressycorrosion c racki ng si s tal solsean ni n ;Ui bends)andli nitheltubes" ivi thi nithej tubeN s u )portt eggcrates dCrac kil i ke~1_ _
lIndicationsishalls >etremovedsfrontservice;by pluggjng'^
orfrepairedibyXsleevin'g M Theitechnica1Tbasestfor sleevinglisidescribediinithetcurrentiNRC(approved AB8;CE ? Techni cal 4reppt ss CEN-630- p ' Revi s i on 72 M Repiip ofl3/4"iO;DR Steam Generator 0 Tubes 1:UsingleaktTight~
Sleeves E :Thi s%i ncl udesitheVi n st al l ati on? proces siand heatitreatmenti proces~s EHeatitreatmentiet tl300? F?to" 425? F! willi bel performedifor337toi 5 [mi nuteh to Geduci residualistressesMThe qualificattunvofsthefsleeyer forjeddy/ current pressure boundar; examination;of/thetsleeve/ tube ysis) described fin) A88sCEireport 96-OSW4003;P2Revisiont00 P EPRisSteam\\ Generator ExaminationEGuidelineslA>pendixTQualificatioMfor o
Wel ded S.l ee_ve} P1 po i rgrobej Exami nat j ongf[AB83 Eddy) Current sh
~~-
Ths* peri od s; betweeEi n spect1 on s"acdodntifoE thei growth i
'oflincipienticrackingitofen'surelthaticracksidoinot"
devel op ei ni servi ceiand tgrowito iai s i re ;thatiwoul d erisk-
)
tuberbursttorfsleeVelburstiduring normal operatingT^~
condi tions c ors dsring i accidentiorzf aul ted(? conditi onsM Thi s imet hodol og'y e and ! the i strust brali marg ~i nTcri teri a" a[e ptated g R3gu]atory Juide @ l21 7 ~ "~ ~
(continued)
SAN ONOFRE--UNIT 2 B 3.4-73 Amendment No. 127
B 3.4.13 BASES--
LC0 I ni spi te fof ?s te am "g' anerat o'rTrepa i rJand Earialys i si to (continued) rehtoreiandidemonstrateiadequate margins againstitube rupture hleakagelhasibeen experiencodifrom tubesiand" sleevesdn PWR steam generatorshfActiversteam' ~
~
generatoritubesdegradationrincreasesitheiprobability 4
ofJleakage. JActive: steam generatoritubeileakagelhas beeniseenfinitheiindustry?to?be!a1frequenttprecursor l
tottubecrupture O Astanieffortstoireducelthesfrecuency andL consequencesiof tube 1rupturesKRegulatorpilanc the~
industry haveD astaiconservative measuresdeveloped~
primary-to-secondary steam generator tubellaakage~~
- guidelinesithat*entailLlower primaryito-secondary leakage limitsifrom steam generator'tubesMThese l
lowertlimits;are documenteciin!EPRIFTR-104788FPWR Primary-to leak measu;-Secondary Leak Gu'ielinestwhichXdescribes rement"methodsYanuimitationsMAlprimaryj to secondary generator;1sf; leakage;1_imittofs150 GPO peristeam arconservativelandiachievable?detectibn l
limitAlleakagefintexcess;of/thiselimitiwilll require plant?shutdowniand antunscheduledLinspectionHduring whichltheileaking<tubejwilgbe;]oc;atedlandMugged og i
fePatred;bLsleev_ing3 APPLICABILITY In MODES 1, 2, 3, and 4, the potential for RCPB LEAKAGE is greatest when the RCS is pressurized.
the rear. tor coolant pressure is far lower, quired because f
In MODES 5 and 6, LEAKAGE limits are not re resulting in lower stresses and reduced potentials for LEAKAGE.-
ACTIONS 6.d Unidentified LEAKAGE, identified LEAKAGE, or primary to secondary LEAKAGE in excess of the LCO limits must be reduced to within limits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
This Completion Time allows time to verify leakage rates and either identify unidentified LEAKAGE or reduce LEAKAGE to within limits before the reactor must be shut down.
This action is necessary to prevent further deterioration of the RCPB.
B.1 and B.R If any pressure boundary LEAKAGE exists or if unidentified, identified, or primary to secondary LEAKAGE-cannot be (continued)
SAN ON0FRE--UNIT 2 B 3.4-74 Amendment No. 127
RCS Operational LEAKAGE-B 3.4.13 BASES 53 - -
ACTIONS B.1 and B.2 (continued) reduced to within limits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, the reactor must be brought to lower pressure conditions to reduce the severity of the LEAKAGE and its potential consequences. The reactor must be brought to MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. This action reduces the LEAKAGE and also reduces the factors that tend to degrade the pressure boundary.
The allowed Completion Times are reasonable, based on operating experience, to reach the required conditions from full power conditions in an orderly manner and without i-challenging plant systems.
In MODE 5, the pressure stresses acting on the RCPB are much lower, and further deterioration is much less likely.
SURVEILLANCE SR 3.4.13.1 REQUIREMENTS Verifying RCS LEAKAGE to be within the LC0 limits ensures the integrity of the RCDB is maintained.
Pressure boundary LEAKAGE would at first appear as unidentified LEAKAGE and can only be positively identified by inspection.
Unider.tified LEAKAGE and identified LEAKAGE are determined by performance of an RCS water inventory balance.
Primary ta secondary LEAKACE is also measured by performance of an LCS water inventory balance in conjunction with effluent monit:: ring within the secondary steam and feedwater systems.
The RCS water inventory balance must be performed with the reactor at steady state operating conditions.
Therefore, this SR is not reouired to be performed in MODES 3 and 4, until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of steady state operation have elapsed.
Steady state operation is required to perform a proper water inventory balance; calculations during maneuvering are not useful and a Note requires the Surveillance to be met when steady state is ertablished.
For RCS operational LEAKAGE determination by water inventory balance, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.
(continued)
SAN ONOFRE--UNIT 2 B 3.4-75 Amendment No. 127 May 29, 1997 4
RCS Operational LEAKAGE B 3.4.13 BASES SURVEILLANCE SR 3.4.13.1 (continued)
REQUIREMENTS An early warning of pressure t,oundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems thr.t monitor the containment atmosphere radioactivity and the containment sump level. These leakage detection systems are specified in LCO 3.4.15, "RCS Leakage Detection Instrumentation "
The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Frequency is a reasonable interval to trend LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents. A Note under the Frequency column states that this SR is required to be performed during steady state operation.
If a transient evolution is occurring 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from the last water inventory balance, then a water inventory balance shall be performed within 120 hours0.00139 days <br />0.0333 hours <br />1.984127e-4 weeks <br />4.566e-5 months <br /> of the last water inventory balance.
l SR 3.4.13.2 This SR provides the means necessary to determine SG OPERABILITY in an operational MODE.
The requirement to demonstrate SG tube integrity in accordance with the Steam Generator Tube Surveillance Program emphasizes the importance of SG tube integrity, even though this Surveillance cannot be performed at normal operating conditions.
REFERENCES 1.
10 CFR 50, Appendix A, GDC 30.
2.
Regulatory Guide 1.45, May 1973.
3.
UFSAR, Section 15.
s l
SAN ON0FRE--UNIT 2 B 3.4-75a Amendment No. 127
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Unit 3
RCS Operational LEAKAGE B 3.4.13 8 3.4 REACTOR COOLANT SYS1EM (RCS)
- B 3.4.13 RCS Operational LEAKAGE BASES BACKGROUND Components that contain or transport the coolant to or from the reactor core make up the RCS, Component joints are made by welding, bolting, rolling, or pressure loading, and valves isolate connecting systems from the RCS, l
During plant life, the joint and velve interfaces can.
produce varying amounts of reactor coolant LEAKAGE, through either normal operational wear or mechanical deterioration.
The purpose of the RCS Operational LEAKAGE LCO is to limit system operation in the presence of LEAKAGE from these sources to amounts that do not compromise safety.
This LC0 specifies the types and amounts of LEAKAGE.
4 10 CFR 50, Appendix A, GDC 30 (Ref. 1), requires means for detecting and, to the extent practical, identifying the source of reactor coolant LEAKAGE.
Regulatory Guide 1.45 (Ref. 2) describes acceptable methods for selecting leakage detection systems.
The safety significance of RCS LEAKAGE varies widely depending on its source, rate, and duration. Therefore, detecting and monitoring reactor coolant LEAKAGE into the containment area is necessary. Quickly separating the identified LEAKAGE from the unidentified LEAKAGE is necessary to provide quantitative information to the operators, allowing them to take corrective sction should a leak occur detrimental to the safety of the facility and the public.
A limited amount of leakage inside containment is expected from auxiliary systems that cannot be made 100% leaktight.
Leakage from these systems should be uetected, located, and i
isolated from the containment atmosphere, if possible, to not interfere with RCS LEAKAGE detection.
This LC0 deals with protection of the reactor coolant pressure boundary (RCPB) from degradation and the core from inadequate cooling, in addition to preventing the accident
- analysis radiation release assumptions from being exceeded.
The consequences of vi:lating this LC0 include the possibility of a loss of coolant accident (LOCA).
(continued)
SAN ON0FRE--UNIT 3 B 3.4-70 Amendment No. 116 1
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RCS Operational LEAKAGE B 3.4.13 BASES (continued)
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APPLICABLE Except for primary to secondary LEAKAGE, the safety analyses SAFETY ANALYSES do not address operational LEAKAGE. However, other operational LEAKAGE is. elated to the safety analyses for LOCA; the amount of leakage can affect the probability of such an event.
The safety analysis for an event resulting in steam discharge to the atmosphere assumes a 1 gpm primary to secondary LEAKAGE as the initial condition.
Primary to secondary LEAKAGE is a factor in the dose releases outside containment resulting from a steam line break (SLB) accident.
To a lesser extent, other accidents or transients involve secondary steam release to the atmosphere, such as a steam generator tube rupture (SGTR).
The leakage contaminates the secondary fluid.
The UFSAR (Ref. 3) analysis for SGTR assumes the contaminated secondary fluid is only briefly released via l
safety valves and the majority is steamed to the condenser.
The 1 gpm primary to secondary LEAKAGE is relatively inconsequential.
1 The SLB is more limiting for site radiation releases. The safety analysis for the SLB accident assumes 1 gpm primary to secondary LEAKAGE in one generator as an initial condition. The dose consequences resulting from the SLB accident are well within the limits defined in 10 CFR 50 or the staff approved licensing basis (i.e., a small fraction of these limits).
RCS operational LEAKAGE satisfies Criterion 2 of the NRC Policy Statement.
LC0 RCS operational LEAKAGE shall be limited to:
a.
Pressure Boundary LEAKAGE No pressure boundary LEAKAGE is allowed, being indicative of material deterioration.
LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LEAKAGE.
Violation of this LC0 could result in continued degradation of the RCPB.
LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.
(continued)
SAN ONOFRE--UNIT 3 8 3.4-71 Amendment No. 116
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RCS Operational LEAKAGE B 3.4.13 BASES (continued)
APPLICABLE Except for primary to secondary LEAKAGE, the safety analyses SAFETY ANALYSES do not address operational LEAKAGE.
However, other operational LEAKAGE is related to the safety analyses for LOCA; the amount of leakage can affect the probability of such an event. The safety analysis for an event resulting in steam discharge to the atmosphere assumes a 1 gpm primary to secondary LEAKAGE as the initial condition.
Primary to secondary LEAKAGE is a factor-in the dose releases outside containment resulting from a steam line break (SLB) accident. To a lesser extent, other accidents or transients involve secondary steam release to the l
atmosphere, such as a steam generator tube rupture (SGTR).
The leakage contaminates the secondary fluid.
The UFSAR (Ref. 3) analysis for SGTR assumes the contaminated secondary fluid is only briefly released via-safety valves and the majority is steamed to the condenser.
The 1 gpm primary to secondary LEAKAGE is relatively inconsequential.
The SLB is more limiting for site radiation releases.
The safety analysis for the SLB accident assumes 1 gpm primary to secondary LEAKAGE in one generator as an initial condition.
The dose consequences resulting from the SLB accident are well within the limits defined in 10 CFR 50 or the staff approved licensing basis (i.e., a small fraction of these limits).
I RCS operational LEAKAGE satisfies Criterion 2 of the NRC Polity Statement.
LC0 RCS operational LEAKAGE shall be limited to:
a.
'No pressure boundary LEAKAGE is allowed, being indicative of material deterioration.
LEAKAGE of this type is unacceptable as the leak itself could cause further deterioration, resulting in higher LFAKAGE.
Violation of this LCO could result' in continued degradation of the RCPB.
LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.
(continued)
SAN 040FRE--UNIT 3 B 3.4-71 Amendment No. 116
RCS Operational LEAKAGE B 3.4.13 BASES.
LC0 b.
-(continued)
One gallon per minute
-allowed as a reasonable (gpm) of unidentified LEAKAGE is minimum detectable amount that the containment air monitoring and containment sump level monitoring equipment can detect within a reasonable time period. Violation of this LC0 could result in continued degradation of the RCPB, if the LEAKAGE is from the pressure boundary.
1 c.
Identified LEAKAGE Up to 10 g)m of identified LEAKAGE is considered allowable )ecause LEAKAGE is from known sources that do not interfere nith detection of identified LEAKAGE and is well within the capability of the RCS makeup system.
Identified LEAKAGE includes LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal i
leakoff (a normal function not considered LEAKAGE).
Violation of this LC0 could result in continued degradation of a component or system.
LCO 3.4.14, "RCS Pressure Isolation Vsive (PIV)
Leakage," measures leakage through each individual PIV-and can impact this LCO. Of-the two PIVs in series in each isolated-line, leakage measured through one PIV I
does not result in RCS LEAKAGE when the other is leaktight.
If both valves leak and result in a loss of mass from the RCS, the loss must be included in the allowable identified LEAKAGE.
d.
-Primary to Secondary LEAKAGE throuah All Steam Generators (SGs)
Total
)rimary to secondary LEAKAGE amounting to 1 gpm througi all SGs produces acceptable off.ite doses in the SLB accident analysis.
Violation of this LC0 could exceed the offsite dose limits for this accident analysis. A%resconseWativeiLColl_imitfof4150: Gilloris Peridayy(GPD)lthrough'ench7steamigenerator11slimpos9 jto d
add re s s ;:s te am ; genera tot t ube isl eev i ng t and is team generatoritube degradation W Thisslimittissimpoked Mn both SGsiin Unitt3;followin llicensingsandsinstallatibn g gajs}9amfgeneyatjy g p e[sjeyvgy g gip py SG[;j g "
(continued)
SAN ON0FRE--UNIT 3 B 3.4-72 Amendment No. 116 n
RCS Operational LEAKAGE B 3.4.13 BASES LC0 b.
Unidentified LEAKAGE (continued)
One gallon per minute (gpm) of unidentified LEAKAGE is allowed as a reasonable minimum detectable amount that the containment air monitoring and containment sump level monitoring equipment can detect within a reasonable time period.
Violation of this LC0 could result in continued degradation of the RCPB, if the LEAKAGE is from the pressure boundary.
c.
Identified LEAKAGE Up to 10 gam of identified LEAKAGE is ennsidered allowable secause LEAKAGE is from known sources that do not interfere with detection of identified LEAKAGE and is well within the capability of the RCS makeup system.
Ider.tified LEAKAGE includes LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal leakoff (a normal function not considered LEAKAGE).
Violation of this LC0 could result in continued degradation of a component or system.
LC0 3.4.14, "RCS Pressure Isolation Valve (PIV)
Leakage," measures leakage through each individual PlV and can impact this LCO.
Of the two PIVs in series in each isolated line, leakage measured through one PIV does not result in RCS LEAKAGE when the other is leaktight.
If both valves leak and result in a loss of mass from the RCS, the loss must be included in the allowable identified LEAKAGE.
d.
Primary to Secondary LEAKAGE throuah All Steam Generators (SGs)
Total primary to secondary LEAKAGE amounting to 1 gpm through all SGs produces acceptable offsite doses in the SLB accident analysis.
Violation of this LC0 could exceed the offsite dose limits for this accident analysis. A'more conservative LC0111mitTof1150 Gallons per?dayT(GPD))through'each steam. generator is. imp.osed to address > steam generator: tube sleeving and: steam ~"
generatoritube degradation. This limit is; imposed?on both SGs in Unit: 3-.following licensing andcinstallation of a steam generatorjtubensleeve.in-either SG. RThe' (continued)
SAN ON0FRE--UNIT 3 B 3.4-72 Amendment No. 116
RCS Operational LEAKAGE B 3.4.13 BASES LCO relationship between leakage limits and tube?
(continued) degradation and sleeving.is discussed in the following section f.
Primary to secondary' LEAKAGE must be' included in the total allowable limit for identified LEAKAGE.
e.
Primary to Secondary LEAKAGE throuah Any One SG The 720 gallon per day limit on primary to secondary LEAKAGE through any one SG allocates the total 1 gpm allowed primary to secondary LEAKAGE equally between the two through' generators. A limit of'150 Gallons per day any one steam generator is imposed on Unit 3 following licensing and i generator. tube sleeves..nstallation of steam f.
Steam tenerator tube: degradation'such as' stress corros'on cracking defects may occur'and.)ropagate from inside or from the outside of-the tu)es,'
particularly in.the areas within the tubesheet'and immediately above the tubesheet.
Stress corrosion cracking is also'seen in U bends and in the tubes ~
j within-the tube support eggeratest Crackelike indications shall be' removed from service by pluging or repaired by sleeving. The technical bases for sleaving is described in the current NRC? approved 4
ABB CE Technical-report - t CEN 630 PAevision 2 " Repair of 3/4" 0.D. Steam Generator Tubes Using Leak Tight '
Sleeves." This' includes the installation pro &ss. and heat treatment process. Heat treatment at.1300"E to"
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1425'F' will be' performed for'3 to -5 minutes.to reduce residuaFstresses.
The qualification of the sleeve:
for eddy. current examination of the sleeve pressure boundary:.is. described in ABB CE r/ tube eport 96 0SW 003 P Revision 00L"EPRI Steam Generator Examination Guidelines Appendix _H Qualification for Eddy Current Plus-Point Probe Eramination of.ABB CE Welde,d S_leeves."
The' periods ~'between inspections accou'nt, forithe' growth of incipient cracking to ensure that cracks do not~
develop-in service and grow to a size that would risk tube. burst or sleeve' burst during normal operatingi conditions or during accident or faulted conditions. -
This methodology and the' structural' margin criteria'
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are stated in Regulatory; Guide 1.121.
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(continued)
SAN ONOFRE-UNIT 3 8 3.4-73 Amendment No, 116
RCS Operational LEAKAGE B 3.4.13 BASES LCO In spite of steam generator repair and analysis to (continued) restore and demonstrate adequate margins against tube rupture,. leakage has been experienced from tubes and sleeves in PWR steam generators. Active steam generator tube degradation increases the probability of Icakage. Active steam generator tube leakage has been seen in the industry to be a frequent precursor to tube rupture. As an effort to reduce the frecuency and consequences of tube ruptures, Regulators anc the industry have, as a conservative measure, developed' primary-to secondary steam generator tube leakage guidelines that entail lower. primary to-secondary leakage limits from steam generator tubes. These lower limits are documented in EPRI 1R 104788, "PWR Primary to Secondary leak Guidelines" which describes leak measurement methods and-limitations. A primary-to secondary leakage limit of 150 GPOlper steam generator is.a conservative and achiev1ble detection limit.
Leakage in excess of this.11mit' will require plant shutdown and an unscheduled inspection-during whichtheleakingtubewillbelocatedandpluggedor repaired by sleeving.
APPLICABILITY In MODES 1, 2, 3, and 4, the potential for RCPB LEAKAGE is greatest when the RCS is pressurized, in MODES S and 6. LEAKAGE limits are not required because the reactor coolant pressure is far lower, resulting in lower stresses and reduced potentials for LEAKAGE.
)
ACTIONS
/k1 Unidentified LEAKAGE, identified LEAKAGE, or primary to secondary LEAKAGE in excess of the LC0 limits must be reduced to within limits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
This Completion Time allows time to verify leakage rates and either identify unidentified LEAKAGE or reduce LEAKAGE to within limits before the reactor must be shut down.
This action is necessary to prevent further deterioration of the RCPB.
B.1 and BJ If any pressure boundary LEAKAGE exists or if unidentified, identified, or primary to secondary LEAKAGE cannot be (continued)
SAN ON0FRE--UNIT 3 8 3.4-74 Amendment No. 116
RCS Operational LEAKAGE B 3.4.13 BASES ACTIONS B.1 and B.2 (continued) reduced to within limits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, the reactor must be brought to lower pressure conditions to reduce the severity of the LEAKAGE and its potential consequences.
The reactor must be brought to MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
This action reduces the LEAKAGE and also reduces the factors that tend to degrade the pressure boundary.
The allowed Completion Times are reasonable, based on operating experience, to reach the required conditions from full power conditions in an orderly manner and without challenging plant systems.
In MODE 5, the 3ressure stresses acting on the RCPB are much lower, and furtier deterioration is much less likely.
SURVEILLANCE SR 3.4.13.1 REQUIREMENTS Verifying RCS LEAKAGE to be within the LCO limits ensures the integrity of the RCPB is maintained.
Pressure boundary LEAKAGE would at first appear as unidentified LEAKAGE and can only be positively identified by inspection.
Unidentified LEAKAGE and identified LEAKAGE are determined by performance of an RCS water inventory balance.
Primary to secondary LEAKAGE is also measured by performance of an RCS water inventory balance in conjunction with effluent monitoring within the secondary steam and feedwater systems.
The RCS water inventory balance must be performed with the reactor at steady state operating conditions.
Therefore, this SR is not required to be performed in MODES 3 and 4, until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of steady state operation have elapsed.
Steady state operation is required to perform a proper water inventory balance; calculations during maneuvering are not useful and a Note reautres the Surveillance to be met when steady state is establisned.
For RCS operational LEAK \\GE determination by water inventory balance, steady state is defined as stable RCS pressure, temperature, power les el, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.
(continued)
SAN ON0FRE UNIT 3 B 3.4-75 Amendment No. 116 May 29, 1997
RCS Operational LEAKAGE B 3.4.13 BASES SURVEILLANCE SR 3.4.13.1 (continued)
REQUIREMENTS An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the_ containment atmosphere radioactivity and the containment sump level.
These leakage detection systerr.s are specified in LCO 3.4.15, "RCS Leakage Detection Instrumentation."
The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Frequency is a reasonable interval to trend LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents. A Note under the Frequency column states that this SR is required to be performed during steady state operation.
If a transient evolution is occurring 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from the last water inventory balance, then a water inventory balance shall be performed within 120 hours0.00139 days <br />0.0333 hours <br />1.984127e-4 weeks <br />4.566e-5 months <br /> of the last water inventory balance.
SR 3.4.13J This SR provides the means necessary to determine SG OPERABILITY in an operational MODE.
The requirement to demonstrate SG tube integrity in accordance with the Steam Generator Tube Surveillance Program emphasizes the importance of SG tube integrity, even though this Surveillance cannot be performed at normal operating conditions.
REFERENCES 1.
10 CFR 50, Appendix A, GDC 30, 2.
Regulatory Guide 1.45, Ma.y 1973.
3.
UFSAR, Section 15.
m SAN ONOFRE--UNIT 3 B 3.4 75a Amendment No. 116
i l
l ENCLOSUllE 3 Ailll/CE PilOPPc:ETAltY AND NON-PitOPillETAltY TOPICAL llEPOllTS CEN-630-P AND CEN-630-NP "llEPAllt OF 3/4" O.D.
STEAM GENEllATOlt TULLES USING LEAK TIGIIT SLEEVES."
l SAN ONOFitE UNITS 2 AND 3 g
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