Text

Proposed Change Number NPF-10/15-564, Application for Technical Specification Improvement Regarding Steam Generator Tube Integrity
	ML053390294
Person / Time
Site:	San Onofre
Issue date:	11/30/2005
From:	Katz B; Southern California Edison Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	Download: ML053390294 (151)
	v • d • e

SOUTHERN CAUFORNIA Brian Katz ED ISO N Vice President An EDISON INTERNAT7ONALO Company November 30, 2005 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

Subject:

Docket Nos. 50-361 and 50-362 Proposed Change Number NPF-10115-564 Application for Technical Specification Improvement Regarding Steam Generator Tube Integrity San Onofre Nuclear Generating Station, Units 2 and 3

Dear Sir or Madam:

In accordance with the provisions of Section 50.90 of Title 10 of the Code of Federal Regulations (10 CFR), Southern California Edison (SCE) is submitting a request for an amendment to the Technical Specifications (TS) for the San Onofre Nuclear Generating Station, Units 2 and 3.

The proposed amendment would revise the TS requirements related to steam generator (SG) tube integrity. The proposed change is based on the NRC-approved Revision 4 to Technical Specification Task Force (TSTF) Standard Technical Specification Change Traveler, TSTF-449, "Steam Generator Tube Integrity." Variations from TSTF-449 are stated in this submittal. The availability of this TS improvement was announced in the Federal Register on May 6, 2005 (70 FR 24126) as part of the consolidated line item improvement process (CLIIP).

Enclosures I and 2 provide notarized affidavits required by 10 CFR 50.30. Enclosure 3 provides the Description and No Significant Hazards Analysis for the proposed amendment.

The proposed amendment is neither exigent nor emergency. SCE requests that the proposed amendments be implemented within 60 days from the date of issuance.

In accordance with 10 CFR 50.91, a copy of this application, with enclosures, is being provided to the designated California State Official.

SCE is making no new commitments that would result from NRC approval of the proposed amendments.

P.O. Box 128 San Clemente, CA 92674-0128 949-368-9275 Fax 949-368-9881

Document Control Desk November 30, 2005 Should you have any questions, or require additional information, please contact Mr. Jack Rainsberry at (949) 368-7420.

Sincerely, Enclosures

1. Notarized affidavit, Unit 2

2. Notarized affidavit, Unit 3

3. Description and No Significant Hazards Analysis cc: B. S. Mallett, Regional Administrator, NRC Region IV N. Kalyanam, NRC Project Manager, San Onofre Units 2 and 3 C. C. Osterholtz, NRC Senior Resident Inspector, San Onofre Units 2 and 3 S. Y. Hsu, Department of Health Services, Radiological Health Branch

Enclosure 1 UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION Application of SOUTHERN CALIFORNIA )

EDISON COMPANY, ET AL. for a Class 103 ) Docket No. 50-361 License to Acquire, Possess, and Use )

a Utilization Facility as Part of ) Amendment Application Unit No. 2 of the San Onofre Nudear ) No. 240 Generating Station)

SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. pursuant to 10 CFR 50.90, hereby submit Amendment Application No. 240. This amendment application consists of Proposed Change No. NPF-10-564 to Facility Operating License NPF-10. Proposed Change No. NPF-10-564 is a request to revise Facility Operating License NPF-10 to incorporate a consolidated line item improvement process (CLIIP) Technical Specification revision related to steam generator (SG) tube integrity.

State of Califomia County of San Diego Brian Katz, Vice Pre ent Subscribed and sworn to (or affirmed) before me on thisgjtffn day of by tSt(A) K Fo ,

personally known to me or-proved te me on thbasikeof satisfact&, ee iee to be the person who appeared before me.

cImmI . 1375470

'Notary Public jX 00-/

Enclosure 2 UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION Application of SOUTHERN CALIFORNIA )

EDISON COMPANY, ET AL. for a Class 103 ) Docket No. 50-362 License to Acquire, Possess, and Use )

a Utilization Facility as Part of ) Amendment Application Unit No. 3 of the San Onofre Nuclear ) No. 224 Generating Station)

SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. pursuant to 10 CFR 50.90, hereby submit Amendment Application No. 224. This amendment application consists of Proposed Change No. NPF-15-564 to Facility Operating License NPF-15. Proposed Change No. NPF-15-564 is a request to revise Facility Operating License NPF-15 to incorporate a consolidated line item improvement process (CLIIP) Technical Specification revision related to steam generator (SG) tube integrity.

State of California County of San Diego Brian Katz, Vice Presi Subscribed and sworn to (or affirmed) before me on this ?W'(Y t Jay of

.P0 Oa -'D by We atV xi .

personally known to me Upie mce on the basis -ofsatis[dacto y evid-en.c to be the person who appeared before me.

Ior~aon 357 Notary Public - In-WcWccu=onga v I

ENCLOSURE 3 Description and No Significant Hazards Analysis for Proposed Change NPF-1 0/1 5-564 San Onofre Nuclear Generating Station Units 2 and 3

LICENSEE'S EVALUATION DESCRIPTION AND NO SIGNIFICANT HAZARDS ANALYSIS FOR PROPOSED CHANGE NPF-101156-64 PROPOSED TECHNICAL SPECIFICATION CHANGE, TECHNICAL SPECIFICATION IMPROVEMENT REGARDING STEAM GENERATOR TUBE INTEGRITY San Onofre Nuclear Generating Station Units 2 and 3 EXISTING TECHNICAL SPECIFICATIONS Unit 2: see Attachment A Unit 3: see Attachment B PROPOSED TECHNICAL SPECIFICATIONS (highlight for additions, strikeout for deletions)

Unit 2: see Attachment C Unit 3: see Attachment D PROPOSED TECHNICAL SPECIFICATIONS (with changes)

Unit 2: see Attachment E Unit 3: see Attachment F PROPOSED TECHNICAL SPECIFICATION BASES (Provided for information / highlight for additions, strikeout for deletions)

Unit 2: see Attachment G (typical for both Units 2 and 3)

1.0 INTRODUCTION

This proposed license amendment revises the requirements in Technical Specifications (TS) related to steam generator tube integrity. The proposed TSs are based on the NRC approved Technical Specification Task Force (TSTF) Standard Technical Specification Change Traveler, TSTF-449, "Steam Generator Tube Integrity," Revision 4, except as stated in Section 2.1. The availability of this Technical Specification improvement was announced in the Federal Register on May 6, 2005 (70 FR 24126) as part of the consolidated line item improvement process (CLIIP).

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2.0 DESCRIPTION

OF PROPOSED AMENDMENT This proposed amendment is based on the NRC-approved Revision 4 of TSTF-449.

Variations from TSTF-449 are stated in the following Section 2.1. The SONGS proposed TS changes include:

Revised TS 1.1 definition of LEAKAGE

Revised TS 3.4.13, "RCS [Reactor Coolant System] Operational Leakage"

New TS 3.4.17, "Steam Generator (SG) Tube Integrity"

Revised TS 5.5.2.11, "Steam Generator (SG) Tube Surveillance Program"

Revised TS 5.7.2, "Special Reports" Proposed revisions to the Unit 2 TS Bases are also included in this application (Attachment G) for information. The proposed TS Bases changes for Unit 2 are typical for both Unit 2 and Unit 3. As discussed in the NRC's model safety evaluation, adoption of the revised TS Bases associated with TSTF-449, Revision 4 is an integral part of implementing this TS improvement. The changes to the affected TS Bases pages will be incorporated in accordance with the TS Bases Control Program (TS 5.4).

2.1 Variations from the CLIIP Since the current SONGS Units 2 and 3 TSs have differences from the latest revision (Rev. 3) of the Combustion Engineering (CE) Improved Standard Technical Specifications (ISTS, NUREG-1432), which was used as the mark-up TSs for TSTF-449, there are some variations to the changes that are needed to incorporate TSTF-449 in the SONGS TSs.

The variations are listed below:

In SR 3.4.13.1 there are site-specific clarifications that were incorporated in current SONGS TSs, when they were updated to the CE Improved Standard Technical Specifications, NUREG-1432 (the mark-up TSs for TSTF-449, Revision 4). This is appropriate because:

o TSTF-449, Revision 4 only added Note 2, and the site-specific clarifications do not affect Note 2.

o The site-specific clarifications have been previously reviewed and approved by the NRC.

In TS 5.5.2.11.b.2 an accident induced leakage performance criterion of 0.5 gallons per minute (gpm) per Steam Generator and 1 gpm through both Steam Generators is proposed. This is appropriate because:

o This is consistent with SONGS accident analysis assumptions.

o This is lower (more conservative) than the value of I gpm per Steam Generator in TSTF-449, Revision 4.

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In TS 5.5.2.11.c the proposed amendment will retain the existing SONGS TS tube repair criteria of 44% of the nominal wall thickness. This varies from the typical value of 40% discussed in the NRC staffs safety evaluation (SE) published on March 2, 2005 (70 FRI 0298) as part of the CLIIP Notice for Comment. This is appropriate because:

o This number is a product of site-specific analysis.

o The analytical basis of the existing criteria is summarized in Updated Final Safety Analysis Report (UFSAR) Section 5.4.2.3.1.3, "Tube Wall Thinning". This includes typical allowances for flaw size measurement error (10%) and incremental crack growth between inspections (10%).

In the TS Bases changes for TS B SR 3.4.13.1, clarification is provided in the text for the new Note 2. The words "primary to secondary" are added before the word "Leakage". This is appropriate because this improves the clarity and accuracy of Note 2.

The TS Bases changes for TS B 3.4.13 and the new TS B 3.4.17 provide more detail than TSTF-449, Revision 4 on the safety analysis assumptions for primary to secondary leakage. The leakage rate is typically expressed in more detail as 0.5 gallons per minute, in each of the two steam generators, rather than the TSTF-449 Revision 4 more generalized expression of 1 gallon per minute total.

This is appropriate because this provides more specificity.

The TS Bases changes for TS B 3.4.13 provide more detail than TSTF-449 Revision 4 on the dose consequence limits reference for Steam Line Break Accident dose consequences. This is appropriate because this provides more specificity.

The TS Bases changes for TS B 3.4.13 and the new TS B 3.4.17 Applicable Safety Analysis reflect the site-specific safety analysis for steam generator (SG) tube rupture. This is appropriate because:

o The context of these TS Bases items are to describe the site-specific safety analysis.

o An assumption of 0.5 gpm leakage is larger than a TSTF-449 Revision 4 specified assumption of 150 gallons per day, providing a larger, more conservative result.

This proposed amendment will retain SONGS TS section numbering. This is a matrix of key section numbers in TSTF-449, Revision 4 and corresponding SONGS TS section numbers. This is appropriate because this minimizes review of format type changes.

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Section Numbers Section Numbers TSTF-449, Revision 4 SONGS TSs 3.4.18 3.4.17 5.5.9 5.5.2.11 5.6.9 5.7.2

3.0 BACKGROUND

The background for this application is adequately addressed by the NRC Notice of Availability published on May 6, 2005 (70 FR 24126), the NRC Notice for Comment published on March 2, 2005 (70 FR 10298), and TSTF-449, Revision 4.

4.0 REGULATORY REQUIREMENTS AND GUIDANCE The applicable regulatory requirements and guidance associated with this application are adequately addressed by the NRC Notice of Availability published on May 6, 2005 (70 FR 24126) the NRC Notice for Comment published on March 2, 2005 (70 FR 10298), and TSTF-449, Revision 4.

5.0 TECHNICAL ANALYSIS

SCE has reviewed the safety evaluation (SE) published on March 2, 2005 (70 FR 10298) as part of the CLIIP Notice for Comment. This included the NRC staffs SE, the supporting information provided to support TSTF-449, and the changes associated with Revision 4 to TSTF-449. SCE has concluded that the justifications presented in the TSTF proposal and the SE prepared by the NRC staff are applicable to SONGS Units 2 and 3 and justify this amendment for the incorporation of the changes to the SONGS Units 2 and 3 TSs.

There are two variations from the SE prepared by the NRC staff. TS 5.5.2.11.b.2 proposes an accident-induced performance criterion of 0.5 gpm per SG and 1 gpm through both SGs, rather than the NRC staff SE Section 3.3.1.2 value of 1 gpm per SG.

TS 5.5.2.11 .c proposes retaining the current TS tube repair criterion of 44%, rather than the NRC staff SE Section 3.3.4 value of 40%. Section 2.1 contains detail on these variations.

SCE's review of the SE prepared by the NRC indicated that a specific Section 1.0 acknowledgement would be applicable within the SE prepared by the NRC for this proposed amendment because existing TSs have a primary to secondary leakage limit that is less restrictive than the proposed 150 gallons per day per SG. The following suggested acknowledgement is provided (with SONGS Units 2 and 3 numerical values) to assist the NRC SE preparer.

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The proposed amendment includes proposed changes to TS 3.4.13 and its bases, "RCS Operational LEAKAGE'. The proposed changes would delete current Limiting Condition for Operation (LCO) limits of 1 gallon per minute total primary-to-secondary leakage through all SGs and 720 gallons per day (gpd) primary-to-secondary leakage through any one SG, and a caveat regarding reduction of these to 150 gpd primary-to-secondary leakage through any one SG with sleeving installed in the Unit. The proposed changes would retain an LCO limit of 150 gpd primary-to-secondary leakage through any one SG, and make it applicable to all SGs. Retaining this LCO limit of 150 gpd primary-to-secondary leakage through any one SG effectively ensures that total primary-to-secondary leakage through all the SGs in a Unit is not allowed to exceed 300 gpd. (Note, San Onofre Unit 2 and 3 plants each have two steam generators.)

5.1 Accident Induced Leakage Performance Cnterion The Nuclear Energy Institute (NEI) provided members the following information and status report in a letter dated September 2, 2005. NEI stated that this was offered for use in license amendment requests. NEI stated that the following information and status report has been reviewed with the NRC.

The industry is currently evaluating a technical issue related to the Accident Induced Leakage Performance Criterion (AILPC) specified in Section 5.5.2.11.b.2 of the proposed Technical Specifications. The issue concerns the consideration of nonpressure (bending) loads on the accident induced leak rates of steam generator tubes (axial differential thermal loads are routinely considered in assessing accident induced leakage). The Electric Power Research Institute (EPRI) Steam Generator Management Program (SGMP) is conducting a study to determine if bending loads are significant, and if they are, to define how to account for the loads in steam generator tube integrity assessments. Inthe interim, as this study is being completed, EPRI has completed a preliminary impact assessment. The assessment (Preliminary Assessment of the Impact of Non-Pressure Loads on Leakage Integrity of Steam Generator Tubing) found that the effect of the loads in question may, in certain circumstances, initiate primary-to-secondary leakage, or increase pre-existing primary-to-secondary leakage during and after load application. The effort also assessed the effect of such loads in combination with the applicable design basis accident. The results indicate that these circumstances are expected to be limited to the presence of significant circumferential cracks located in high bending stress regions of tubing. As of this date, such degradation has not been observed in the industry.

The structural integrity impact of non-pressure loads on degraded steam generator tubes has been well-documented in a previous EPRI report (NRC accession number ML050760208) related to the revised Structural Integrity Performance Criterion (SIPC).

Experimental results indicated that neither axial loads nor bending loads have a significant effect on the burst pressure of tubing with axial degradation. Similarly, these loads are considered inconsequential for axially oriented degradation with respect to localized pop-through conditions and corresponding accident leakage. As such, 5

industry experience indicates that the only meaningful impact of non-pressure loads with respect to leakage are due to the application of bending moments on circumferential cracking.

The EPRI Preliminary Assessment found that high bending loads that could affect the leakage analysis are only present in the top span region in the original design of once-through steam generators (OTSGs) and in the U-bend region of large-radius tubes in some recirculating steam generators. The high bending loads in the OTSGs are a consequence of crossflow during a steam line break whereas the high bending loads in the recirculating steam generators are a result of a seismic event.

After review of available analysis and experimental data, the EPRI Assessment concluded that the effect of high bending loads is only noteworthy for large 100% or near through-wall circumferential degradation. From a degradation assessment perspective, the EPRI study also reported that current industry experience indicates that there have been no observed stress corrosion circumferential cracks that are both capable of leaking and located in high bending stress regions. The industry's preliminary impact assessment and the plans for the further technical study and experimental testing were presented to the NRC Staff in a meeting on August 12, 2005.

The NRC Staff did not have any significant comments on the results presented.

Based on the above, Southem Califomia Edison believes that the effect of bending loads is not safety significant for San Onofre with respect to leakage integrity given the expected effect and existing margins with respect to degradation type, susceptible location and allowable flaw size.

If upon completion of EPRI's technical study, it is concluded that the effect of nonpressure loads, including bending loads, should be specifically accounted for in integrity assessments, the industry will revise the applicable steam generator program guideline documents to reflect the means developed to account for the loads.

6.0 REGULATORY SAFETY ANALYSIS A description of this proposed change and its relationship to applicable regulatory requirements and guidance was provided in the NRC Notice of Availability published on May 6, 2005 (70 FR 24126), the NRC Notice for Comment published on March 2, 2005 (70 FR 10298), and TSTF-449, Revision 4.

6.1 Verification and Commitments: CLIIP Changes The following information is provided to support the NRC staff's review of this amendment application. This information was current when assembled on September 30, 2005:

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PlantlUnit SONGS Unit 2 SONGS Unit 3 Steam Generator Model Combustion Engineering Combustion Engineering 3410 3410 Effective full power years 18 17 (EFPY) of service for currently installed SGs Tubing material Alloy 600 Mill Annealed Alloy 600 Mill Annealed Number of tubes per SG 9,350 9,350 Number and percentage of SG E-088: 939 (10.2% SG E-088: 704 (7.6% tubes tubes plugged in each SG effective plugged) plugged)

(For Unit 2 this is effective SG E-089: 960 (10.4% SG E-089: 651 (7.0% tubes plugging" which includes effective plugged) plugged) equivalent effect (38 sleeves per plug) of inservice repaired tubes)

Number of tubes repaired in SG E-088: 345 None each SG that are inservice SG E-089: 189 Degradation mechanism o Inside diameter (ID) O ID axial and identified axial and circumferential circumferential within within tubesheet and at tubesheet and at expansion transition expansion transition o Outside diameter o OD axial and (OD) axial and circumferential at circumferential at expansion transition expansion transition o OD axial in tubing o OD axial in tubing freespan and at tube freespan and at tube supports supports o ID axial at dented o Wear at supports and tube supports loose parts o Wear at supports and o ID axial and loose parts circumferential at U-bend o ID axial at U-bend o Inward-yielding at sleeves Current primary-to- 150 gpd per SG 720 gpd per SG secondary leakage limits, (TS 3.4.13) at room (TS 3.4.13) at room evaluated at what temperature temperature because temperature condition sleeving has not been installed at Unit 3.

150 gpd per SG (TS 3.4.13) at room temperature, when 7

Plant/Unit SONGS Unit 2 SONGS Unit 3 sleeving is installed at Unit 3.

Approved alternate tube None None repair criteria Approved SG Tube Repair Approved by Amendment Approved by Amendment Methods Number 140 dated 8/26/98 Number 132 dated 8/26/98 Installation of Tungsten Installation of TIG welded Inert Gas (TIG) welded sleeving as described in sleeving as described in ABB/CE Topical Report, ABB/CE Topical Report, CEN-630-P, Rev. 2 CEN-630-P, Rev. 2 Sleeve repair criteria: Sleeve repair criteria:

Sleeves shall be removed Sleeves shall be removed from service upon detection from service upon detection of service induced of service induced degradation of the sleeve degradation of the sleeve material or any portion of material or any portion of the sleeve-to-tube weld the sleeve-to-tube weld Performance criteria for 0.5 gpm per SG 0.5 gpm per SG accident leakage 7.0 NO SIGNIFICANT HAZARDS CONSIDERATION Southern California Edison (SCE) has reviewed the no significant hazards consideration determination published on March 2, 2005 (70 FR 10298) as part of the Consolidated Line Item Improvement Process (CLIIP). SCE has concluded that the proposed determination presented in the notice is applicable to San Onofre Units 2 and 3 and the evaluation is hereby incorporated by reference to satisfy the requirements of 10 CFR 50.91(a). SCE is not proposing variations or deviations from the proposed no significant hazards consideration determination, except for the following:

The San Onofre Nuclear Generating Station (SONGS) SG tube rupture analysis conservatively assumes a leakage of 0.5 gpm (720 gpd) from each SG instead of the operational leakage limit of 150 gpd that is described in the No Significant Hazards Consideration discussion in the Technical Specification Task Force (TSTF)-

449 safety evaluation. This is appropriate because:

o The context of this is to describe the site-specific safety analysis.

o An assumption of 0.5 gpm leakage is larger than a TSTF-449 Revision 4 specified assumption of 150 gallons per day, providing a larger, more conservative analysis result.

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The proposed Technical Specifications (TSs) are based on the NRC approved TSTF Standard Technical Specification Change Traveler, TSTF-449, "Steam Generator Tube Integrity," Revision 4. Some variations from TSTF-449 are needed to incorporate TSTF-449 in the SONGS TSs. These variations are discussed in the proposed amendment.

8.0 ENVIRONMENTAL EVALUATION SCE has reviewed the environmental evaluation included in the model SE published on March 2, 2005 (70 FR 10298) as part of the CLIIP. SCE has concluded that the staffs findings presented in that evaluation are applicable to SONGS Units 2 and 3 and the evaluation is hereby incorporated by reference for this application.

9.0 PRECEDENT This application is being made in accordance with the CLIIP. SCE is proposing variations, that are discussed in Section 2.1, from the TS changes described in TSTF-449, Revision 4. SCE is not proposing variations or deviations from the NRC staffs model SE published on March 2, 2005 (70 FR 10298), except for the following:

Section 5.0 addressed two proposed variations.

Section 7.0 addressed that the SONGS SG tube rupture analysis conservatively assumes a leakage of 0.5 gpm (720 gpd) from each SG instead of the operational leakage limit of 150 gpd that is described in the No Significant Hazards Consideration discussion in the TSTF-449 safety evaluation.

10.0 REFERENCES

Federal Register Notices:

Notice for Comment published on March 2, 2005 (70 FR 10298)

Notice of Availability published on May 6, 2005 (70 FR 24126)

Attachment A (Existing Pages)

SONGS Unit 2

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation ................ 3.3-22 3.3.6 Engineered Safety Features Actuation System (ESFAS)

Logic and Manual Trip ............. 3.3-27 3.3.7 Diesel Generator (DG) -Undervoltage Start . . . . . 3.3-32 3.3.8 Containment Purge Isolation Signal (CPIS) . . . . . 3.3-35 3.3.9 Control Room Isolation Signal (CRIS) ....... 3.3-39 3.3.10 Fuel Handling Isolation Signal (FHIS) . . .. 3.3-42 3.3.11 Post Accident Monitoring Instrumentation (PAMI) 3.3-44 3.3.12 Remote Shutdown System .............. 3.3-48 3.3.13 Source Range Monitoring Channels ......... 3.3-51 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . 3.4-1 3.4.1 RCS DNB Pressure, Temperature, and Flow Limits. . . 3.4-1 3.4.2 RCS Minimum Temperature for Criticality .... 3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . . . 3.4-5 3.4.3.1 Pressurizer Heatup/Cooldown Limits . . . . . . . . . 3.4-13 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . . . . . 3.4-15 3.4.5 RCS Loops- MODE 3.. . 3.4-16 3.4.6 RCS Loops- MODE 4 .3.4-'18' 3.4.7 RCS Loops -MODE 5, Loops Filled . . . . . . . . . . 3.4-21 3.4.8 RCS Loops- MODE 5, Loops Not Filled . . . . . . . . 3.4-24 3.4.9 Pressurizer . . . . . . . . . . . . . . . . . . . . 3.4-26 3.4.10 Pressurizer Safety Valves . . . . . . . . . . . . .. 3.4-28 3.4.11 Not Used 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature 5 2560F . . . . . . . . 3.4-30 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 256 0F . . . . . . . . 3.4-35 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . . . 3.4-37 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . . . . 3.4-39 3.4.15 RCS Leakage Detection Instrumentation . . . . . . . 3.4-44 3.4.16 RCS Specific Activity . ... . . . . . . . . . . . . 3.4-47 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . .3.5-1 3.5.1 Safety Injection Tanks (SITs) . . .. .. . 3.5-1 3.5.2 ECCS- Operating . . . . . . . . . .. .. . . . .. 3.5-4 3.5.3 ECCS- Shutdown . . . . . . . . . . .. .. . . . .. 3.5-8 3.5.4 Refueling Water Storage Tank (RWST) . .. . . . . . 3.5-9 3.5.5 Trisodium Phosphate (TSP) . . . . .. .. . . . .. 3.5-11 (continued)

SAN ONOFRE--Unit 2 iii Amendment No. 127

TABLE OF CONTENTS B 3.3 INSTRUMENTATION (continued)

B 3.3.7 Diesel Generator Undervoltage Start . . . . . . B 3.3-126 B 3.3.8 Containment Purge Isolation Signal (CPIS) . . . B 3.3-135 B 3.3.9 Control Room Isolation Signal (CRIS) . . . . . . B 3.3-145 B 3.3.10 Fuel Handling Isolation Signal (FHIS) . . . . . B 3.3-152 B 3.3.11 Post Accident Monitoring Instrumentation (PAMI) B 3.3-159 B 3.3.12 Remote Shutdown System . . . . . . . . . . . . . B 3.3-176 B 3.3.13 Source Range Monitoring Channels . . . . . . . . B 3.3-181 B 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . B 3.4-1 B 3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits B 3.4-1 B 3.4.2 RCS Minimum Temperature for Criticality . . . . B 3.4-7 B 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . B 3.4-9 B 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . . . B 3.4-23 B 3.4.5 RCS Loops -MODE 3 . . . . . . . . . . . . . . . B 3.4-27 B 3.4.6 RCS Loops -MODE 4 . . . . . . . . . . . . . . . B 3.4-31 B 3.4.7 RCS Loops -MODE 5, Loops Filled . . . . . . . . B 3.4-36 B 3.4.8 RCS Loops -MODE 5, Loops Not Filled . . . . . . B 3.4-42 B 3.4.9 Pressurizer . . . . . . . . . . . . . . . . . . B 3.4-46 B 3.4.10 Pressurizer Safety Valves . . . . . . . . . . . B 3.4-51 B 3.4.11 Not Used B 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature 5 256°F . . . . . . B 3.4-55 B 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 256OF . . . . . . . B 3.4-65 B 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . B 3.4-70 B 3.4.14- RCS Pressure-Isolation Valve (PIV) Leakage . . . B 3.4-76 B 3.4.15 RCS Leakage Detection Instrumentation . . . . . B 3.4-82 B 3.4.16 RCS Specific Activity . . . . . . . . . . . . . B 3.4-88 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . . . . . . B 3.5-1 B 3.5.1 Safety Injection Tanks (SITs) B 3.5-1 B 3.5.2 ECCS -Operating . . . . . . . . . B 3.5-11 B 3.5.3 ECCS -Shutdown . B 3.5-21 B 3.5.4 Refueling Water Storage Tank (RWST). B 3.5-24 B 3.5.5 Trisodium Phosphate (TSP) . . . . . . . . . . . B 3.5-30 B 3.6 CONTAINMENT SYSTEMS . . . . . . . . . . B 3.6-1 B 3.6.1 Containment . . . . .. B 3.6-1 B 3.6.2 Containment Air Locks. B 3.6-5 B 3.6.3 Containment Isolation Valves . . . . B 3.6-13 B 3.6.4 Containment Pressure . . . . . . . . B 3.6-27 B 3.6.5 Containment Air Temperature . . . . B 3.6-30 B 3.6.6.1 Containment Spray and Cooling System B 3.6-33 B 3.6.6.2 Containment Cooling System . . . . . B 3.6-43 B 3.6.7 Hydrogen Recombiners . . . . . . . . B 3.6-48 B 3.6.8 Containment Dome Air Circulators . . B 3.6-53 (continued)

SAN ONOFRE--Unit 2 vii Amendment No. 127

Definitions 1.1 1.1 Definitions ENGINEERED SAFETY measurement, response time may be verified for FEATURE (ESF) RESPONSE selected components provided that the components TIME (Continued) and methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator (SG) to the Secondary System.

b. Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c. Pressure Boundary LEAKAGE LEAKAGE (except SG LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

(continued)

SAN ONOFRE--UNIT 2 1.1-4 Amendment No. 188 1

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 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; NOTE: With no SG sleeving installed, d. and e. apply.

Following installation of any sleeving in any SG, d.

and e. do not apply and f. does apply.

d. 1 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.

f. With steam generator sleeving installed in any SG ,

150 gallons per day primary to secondary LEAKAGE through any one SG.

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

SAN ONOFRE--UNIT 2 3.4-37 Amendment No. 127~ 140

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 -------------------NOTE-------------------- ----- NOTE------

Not required to be performed in MODE 3 or 4 Only required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation. to be performed during steady state operation.

If a transient Perform RCS water inventory balance. evolution is occurring 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the last water inventory balance, then a water inventory balance shall be performed.

with in 120 hours0.00139 days 0.0333 hours 1.984127e-4 weeks 4.566e-5 months of the last water.

inventory balance 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.4.13.2 Verify SG tube integrity is in accordance In accordance with the Steam Generator Tube Surveillance with the Steam Program. Generator Tube Surveillance Program SAN ONOFRE--UNIT 2 3.4-38 Amendment No. 127

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only until such time as a modification eliminates the post-accident piping as a potential leakage path). The program shall include the fol owing:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. Program itself is relocated to the LCS.

5.5.2.10 Inservice Inspection and Testing Program This program provides controls for inservice inspection of ASME Code Class 1, 2, and 3 components and Code Class CC and MC components including applicable sup orts. The program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components- The program itself is located in the LCS.

5.5.2.11 Steam Generator (SG) Tube Surveillance Program This program provides controls for monitoring SG tube degradation.

Each SG shall be demonstrated OPERABLE by meeting the requirements of Specification 5.5.2.11 and by meeting an augmented inservice inspection program based on a modification of Regulatory Guide 1.83, Revision 1, which includes at least the following:

a. SG Sample Selection and Inspection Each SG shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum number of SG specified in Table 5.5.2.11-1 and 5.5.2.11-2.

b. SG Tube Sample Selection and Inspection The SG tube and sleeve minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5.2.11-1 and 5.5.2.11-2. The inservice inspection of SG tubes and sleeves shall be performed at the frequencies specified in Specification 5.5.2.11.e and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.2.11.f. The tubes selected for each inservice inspection shall include at least 3% of the total (continued)

SAN ONOFRE--UNIT 2 5.0-13 Amendment No. 147,168,178 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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 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 each SG shall include:

a) All non-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 5.5.2.11.f) shall be performed on each selected tube. If any selected tube does not permitt'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 eddy current prior to initial operation . This includes pressure retaining portions of the parent tube in contact with the sleeve, the sleeve-to-tube weld and the pressure retaining portion of the sleeve.

4. Following the preservice inspection, 20% of sleeves that have been in service for a full cycle of operation shall be inspected. The sleeves shall be selected on 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 sample expansion.

(continued)

SAN ONOFRE--UNIT 2 5.0-14 Amendment No. -2* 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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.

This classification shall also apply to sample inspections of sleeves.

NOTE----------_-_-_-____-

In all inspections, previously degraded non-repaired tubes 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 ONOFRE--UNIT 2 5.0-15 Amendment No. +Ai 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued)

e. Inspection Frequency The above required inservice inspections of the non-repaired 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 5.5.2.11.e.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 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 ONOFRE--UNIT 2 .5.0-16 Amendment No. 4-27 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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 above required inservice inspections of SG tubes repaired by sleeving shall be performed at the following frequencies:

1. Steam generator tube sleeves shall be inspected prior to initial operation and in service. The initia operating period before the initial inservice sample inspection shall not be shorter than six months nor longer than 24 months. The inspections of sleeves shall be configured to ensure that each individual sleeve is inspected at least once in 60 months.

2. If the results of the inservice inspection of SG tube sleeves conducted in accordance with Table 5.5.2.11-2 fall in category C-3, 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 shall apply until the subsequent inspections satisfy the criteria for Category C-1.

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 repair limit. A tube containing a defect is defective.

(continued)

SAN ONOFRE--UNIT 2 5.0-17 Amendment No. i24 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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) Repair Limit - 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 techniquesr 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 portion of the sleeve.

h) Tube Inspection - An inspection of the SG tube from the point of entr (hot leg side) completely around the U-bend to the top support of the cold leg excluding the portion of the tube within the tubesheet (TS) below 5 inches from the secondary face of the TS.*

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 5.5.2.11.e.

This exclusion is for Unit 2, Cycle 12 operation only.

(continued)

SAN ONOFRE--UNIT 2 5.0-18 Amendment No. 189

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) j) Tube Re pair - refers to a process that reestablishes tube serviceability. Acceptable 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 previously plugged tube prior to returning the tube to service.

2. The SG shall be determined OPERABLE after completing the corresponding actions (plug or repair all tubes exceeding the repair limit and all tubes containing through-wall cracks, and plug all sleeved tubes that exceed the repair criteria) required by Tables 5.5.2.11-1 and 5.5.2.11-2.

9. Reports The content and frequency of written reports shall be in accordance with Technical Specification 5.7.2, "Special Reports."

(continued)

SAN ONOFRE--UNIT 2 5.0-19 Amendment No. +2* 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator Tube Surveillance Program TABLE 5.5.2.11-1 (page 1 of 1)

STEAM GENERATOR TUBE INSPECTION SUPPLEMENTAL SAMPLING REQUIREMENTS 1st Sample Inspection 2nd Sample Inspection 3rd Sample Inspection lAction Action Action Sample Size Result Required Result I Required Result Required II Acin.Ato _____j Ato A minimum of C-1 None N/A N/A N/A N/A S tubes per SG C-2 Plug or repair C-1 None N/A N/A by sleeving defective tubes C-2 Plug or repair by and inspect an sleeving defective additional 2S tubes and C-1 NONE tubes in this inspect an SG. additional 4S C-2 Plug or repair tubes in this SG. by sleeving defective.

tubes.

C-3 Performi actior for C-3 result of first sample.

C-3 Perform N/A N/A action for C-3 result of first sample.

+/-

C-3 Inspect all All other SGs None N/A N/A tubes in this C-1 SG, plug or repair by sleeving Some SGs C-2 Perform N/A N/A defective tubes but no other action for and inspect 2S is C-3 C-2 result of tubes in each second other SG. sample.

Noti fication to NRC Additional SG Inspect all tubes pursuant to is C-3 in each SG and N/A N/A 5.7.2 plug or repair by sleeving defective tubes.

Notification to NRC pursuant to 5.7.2 S = 3 N/n % Where N is the number of SGs in the unit and n is the number of SGs inspected during an inspection. I (continued)

SAN ONOFRE--UNIT 2 5.0-19a Amendment No. +-4-7-168 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) I 5.5.2.11 Steam Generator Tube Surveillance Program (continued)

Table 5.5.2.11-2 (page 1 of 1)

Steam Generator Sleeved Tube Inspection I

Sample Size 1st Sample Inspection Result Action Required I 2nd Sample Inspection Result Action Required I 1 C-1 None N.A. N.A.

Plug defective C-1 None repaired tubes C-1 l_ None and inspect Plug defective, 100% of the C-2 repaired tubes.

C-2 sleeves in this Perform action SG for C-3 result C-3 of first sample.

Inspect all repaired tubes Other SG is C-1 None in this SG, A minimum of plug defective 20% of the repaired tubes, sleeves. Perform action and inspect 20%

of the sleeves Other SG is C-2 for C-2 result of first in the other sample.

SG.

C-3 Inspect all Notification to repaired tubes NRC pursuant to in both SG's 5.7.2 and plug defective Other SG is C-3 repaired tubes.

Notification to NRC pursuant to 5.7.2

& I & &

(continued)

SAN ONOFRE--UNIT 2 5.0-19b Amendment No. +409168 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator 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-accident Cleanup Filter System." The frequency of testing shall be in I 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 ANSI N510-1975 (see Note 1); 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 ANSI N510-1975 (see Note 1); and I

c. Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested per the methodology of ASTM D3803-1989 at 300C and 70%

relative humidity 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.

Note 1: Sample and injection points shall be qualified per ANSI N510-1975 unless manifolds have been qualified per ASME N510-1989.

HEPA testing will be conducted with DOP aerosol or suitable alternate.

(continued)

SAN ONOFRE--UNIT 2 5.0-19c Amendment No. 140, 187

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (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 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 G 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 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.

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 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 sleeves 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 ONOFRE--UNIT 2 5.0-30 Amendment No. 194 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.7.2 Special Reports (continued)

Results of SG tube inspections which fall into Category C-3 shall be reported to the NRC prior to resumption of plant operation. This report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrence.

SAN ONOFRE--UNIT 2 5.0-31 Amendment No. 127

Attachment B (Existing Pages)

SONGS Unit 3

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation.. .......... 3.3-22 3.3.6 Engineered Safety Features Actuation System (ESFAS)

Logic and Manual Trip ............. 3.3-27 3.3.7 Diesel Generator (DG) -Undervoltage Start . . . . .

3.3-32 3.3.8 Containment Purge Isolation Signal (CPIS) . . . . . 3.3-35 3.3.9 Control Room Isolation Signal (CRIS) ....... 3.3-39 3.3.10 Fuel Handling Isolation Signal (FHIS) . . . . . . . 3.3-42 3.3.11 Post Accident Monitoring Instrumentation (PAMI) 3.3-44 3.3.12 Remote Shutdown System . . . . . . . . . . . . . . 3.3-48 3.3.13 Source Range Monitoring Channels ......... 3.3-51 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . 3.4-1 3.4.1 RCS DNB Pressure, Temperature, and Flow Limits .. 3.4-1 3.4.2 RCS Minimum Temperature for Criticality . .3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . . . 3.4-5 3.4.3.1 Pressurizer Heatup/Cooldown Limits . . . . . . . . . 3.4-13 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . . . . . 3.4-15 3.4.5 RCS Loops -MODE 3 ............. . . 3.4-16 3.4.6 RCS Loops- MODE 4 ..... ...... .. . . . . 3.4-18 3.4.7 RCS Loops -MODE 5. Loops Filled . . .. . . . . . . 3.4-21 3.4.8 RCS Loops -MODE 5. Loops Not Filled . ... . . . . 3.4-24 3.4.9 Pressurizer . . . . .. . . . . . . . . . . . . . . 3.4-26 3.4.10 Pressurizer Safety Valves . . ... . . . . . . . . 3.4-28 3.4.11 Not Used 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature

246 0F . . . . . . . . 3.4-30 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 2460 F . .. . . . . . 3.4-35 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . . . 3.4-37 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . . . . 3.4-39 3.4.15 RCS Leakage Detection Instrumentation . . . . . . . 3.4-44 3.4.16 RCS Specific Activity . . . . . . . . . . . . . . 3.4-47 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . . . . . . . . 3.5-1 3.5.1 Safety Injection Tanks (SITs) . . . . . . . . . . . 3.5-1 3.5.2 ECCS- Operating . . . . . . . . . . . . . . . . . . 3.5-4 3.5.3 ECCS -Shutdown . . . . ... . . . . . . . . . . . . . 3.5-8 3.5.4 Refueling Water Storage Tank (RWST) . . . . . . . . 3.5-9 3.5.5 Trisodium Phosphate (TSP) . . . . . . . . . . . . . 3.5-11 (continued)

SAN ONOFRE--Unit 3 iii Amendment No. 116

TABLE OF CONTENTS B 3.3 INSTRUMENTATION (continued)

B 3.3.7 Diesel Generator Undervoltage Start B 3.3-126 B 3.3.8 Containment Purge Isolation Signal (CPIS) . . . B 3.3-135 B 3.3.9 Control Room Isolation Signal (CRIS) . . . . . . B 3.3-145 B 3.3.10 Fuel Handling Isolation Signal (FHIS) . . . . . B 3.3-152 B 3.3.11 Post Accident Monitoring Instrumentation (PAMI) B 3.3-159 B 3.3.12 Remote Shutdown System . . . . . . . . . . . . . B 3.3-176 B 3.3.13 Source Range Monitoring Channels . . . . . . . . B 3.3-181 B 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . B 3.4-1 B 3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits B 3.4-1 B 3.4.2 RCS Minimum Temperature for Criticality . . . . . B 3.4-7 B 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . . B 3.4-9 B 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . . . . B 3.4-23 B 3.4.5 RCS Loops -MODE 3 ................ B 3.4-27 B 3.4.6 RCS Loops -MODE 4 . . . . . . . . . . . . . . . . B 3.4-31 B 3.4.7 RCS Loops- MODE 5, Loops Filled . . . . . . . . . B 3.4-36 B 3.4.8 RCS Loops -MODE 5, Loops Not Filled . . . . . . . B 3.4-42 B 3.4.9 Pressurizer . . . . . . . . . . B 3.4-46 B 3.4.10 Pressurizer Safety Valves B 3.4-51 B 3.4.11 Not Used B 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature s 246°F . . . . . . . B 3.4-55 B 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 246°F . . . . . . . . B 3.4-65 B 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . . B 3.4-70 B 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . . . B 3.4-76 B 3.4.15 RCS Leakage Detection Instrumentation . . . . . . B 3.4-82 B 3.4.16 RCS Specific Activity . . . . . . . . . . . . . . B 3.4-88 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) B 3.5-1 B 3.5.1 Safety Injection Tanks (SITs) . . . B 3.5-1 B 3.5.2 ECCS -Operating . . . . . . . . . . B 3.5-11 B 3.5.3 ECCS -Shutdown . B 3.5-21 B 3.5.4 Refueling Water Storage Tank (RWSi) B 3.5-24 B 3.5.5 Trisodium Phosphate (TSP) . . . . . B 3.5-30 B 3.6 CONTAINMENT SYSTEMS . . . . . . . . . . B 3.6-1 B 3.6.1 Containment . . . . . . . . . . . . B 3.6-1 B 3.6.2 Containment Air Locks . . . . . . . B 3.6-5 B 3.6.3 Containment Isolation Valves . . . . B 3.6-13 B 3.6.4 Containment Pressure . . . . . . . . B 3.6-27 B 3.6.5 Containment Air Temperature . . . . B 3.6-30 B 3.6.6.1 Containment Spray and Cooling System B 3.6-33 B 3.6.6.2 Containment Cooling System . . . . . B 3.6-43 B 3.6.7 Hydrogen Recombiners . . . . . . . . B 3.6-48 B 3.6.8 Containment Dome Air Circulators . . B 3.6-53 (continued)

SAN ONOFRE--Unit 3 vii Amendment No. 116

Definitions 1.1 1.1 Definitions ENGINEERED SAFETY measurement, response time may be verified for FEATURE (ESF) RESPONSE selected components provided that the components TIME (Continued) and methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator (SG) to the Secondary System.

b. Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c. Pressure Boundary LEAKAGE LEAKAGE (except SG LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

(continued)

SAN ONOFRE--UNIT 3 1.1-4 Amendment No. 116

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 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; NOTE: With no SG sleeving installed, d. and e. apply.

Following installation of any sleeving in any SG, d.

and e. do not apply and f. does apply.

d. 1 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.

f. With steam generator sleeving installed in any SG, 150 gallons per day primary to secondary LEAKAGE through any one SG.

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

(continued)

SAN ONOFRE--UNIT 3 3.4-37 Amendment No. +-1 132

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.13.1 ------------------- NOTE--------------- ----- NOTE------

Not required to be performed in MODE 3 or 4 Only required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation. to be performed during steady state operation.

If a transient Perform RCS water inventory balance. evolution is occurring 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the last water inventory balance, then a water inventory balance shall be performed within 120 hours0.00139 days 0.0333 hours 1.984127e-4 weeks 4.566e-5 months of the, last water inventory balance 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.4.13.2 Verify SG tube integrity is in accordance In accordance with the Steam Generator Tube Surveillance with the Steam Program. Generator Tube Surveillance Program (continued)

SAN ONOFRE--UNIT 3 3.4-38 Amendment No. 116

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only until such time as a modification eliminates the post-accident piping as a potential leakage path). The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. Program itself is relocated to the LCS.

5.5.2.10 Inservice Inspection and Testing Program This rogram provides controls for inservice inspection of ASME Code Class 1, 2, and 3 components and Code Class CC and MC components including applicable supports. The program provides' controls for inservice testing of ASME Code Class 1, 2, and 3 components. Program itself is located in the LCS.

5.5.2.11 Steam Generator (SG) Tube Surveillance Program This program provides controls for monitoring SG tube degradation.

Each SG shall be demonstrated OPERABLE by meeting the requirements of Specification 5.5.2.11 and by meeting an augmented inservice inspection program based on a modification of Requlatory Guide 1.83, Revision 1, which includes at least the following:

a. SG Sample Selection and Inspection Each SG shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum number of SG specified in Table 5.5.2.11-1 and 5.5.2.11-2.

b. SG Tube Sample Selection and Inspection The SG tube and sleeve minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5.2.11-1 and 5.5.2.11-2.

The inservice inspection of SG tubes and sleeves shall be performed at the frequencies specified in Specification 5.5.2.11.e and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.2.11.f. The tubes selected for each inservice inspection shall include at least 3% of the total (continued)

SAN ONOFRE--UNIT 3 5.0-13 Amendment No. 139,159,169 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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 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 each SG shall include:

a) All non-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 5.5.2.11.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.

3. All sleeves shall be inspected with eddy current prior to initial operation. This includes pressure retaining portions of the parent tube in contact with the sleeve, the sleeve-to-tube weld and the pressure retaining portion of the sleeve.

4. Following the preservice inspection, 20% of sleeves that have been in service for a full cycle of operation shall be inspected. The sleeves shall be selected on 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 sample expansion.

(continued)

SAN ONOFRE--UNIT 3 5.0-14 Amendment No. +&6 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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.

This classification shall also apply to sample inspections of sleeves.

_ _-__ __---------- NOTE----------------------

In all inspections, previously degraded non-repaired tubes 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 ONOFRE--UNIT 3 5.0-15 Amendment No. +%S 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued)

e. Inspection Frequency The above required inservice inspections of the non-repaired 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 aSG 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 5.5.2.11.e.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 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 ONOFRE--UNIT 3 5.0-16 Amendment No. 4+6 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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 above required inservice inspections of SG tubes repaired by sleeving shall be performed at the following frequencies:

1. Steam generator tube sleeves shall be inspected rior to initial operation and in service. The initia operating period before the initial inservice sample inspection shall not be shorter than six months nor longer than 24 months. The inspections of sleeves shall be configured to ensure that each individual sleeve is inspected at least once in 60 months.

2. If the results of the inservice inspection of SG tube sleeves conducted in accordance with Table 5.5.2.11-2 fall in category C-3, 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 shall apply until the subsequent inspections satisfy the criteria for Category C-1.

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 repair limit. A tube containing a defect is defective.

(continued)

SAN ONOFRE--UNIT 3 5.0-17 Amendment No. 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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) Repair Limit - 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.

imilarly, 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 portion of 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 le excluding the portion of the tube within the tubesheet (TS) below 5 inches from the secondary face of the TS.*

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 5.5.2.11.e.

This exclusion is for Unit 3, Cycle 11 operation only.

(continued)

SAN ONOFRE--UNIT 3 5 .0-18 Amendment No. 180

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) j) Tube Re pair - refers to a process that reestablishes tube serviceability. Acceptable 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 previously plugged tube prior to returning the tube to service.

2. The SG shall be determined OPERABLE after completing the corresponding actions (plug or repair all tubes exceeding the repair limit and all tubes containing through-wall cracks, and plug all sleeved tubes that exceed the repair criteria) required by Tables 5.5.2.11-1 and 5.5.2.11-2.

9. 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 5.0-19 Amendment No. 116 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator Tube Surveillance Program TABLE 5.5.2.11-1 (page 1 of 1)

STEAM GENERATOR TUBE INSPECTION SUPPLEMENTAL SAMPLING REQUIREMENTS 1st Sample Inspection 2nd Sample Inspection 3rd Sample Inspection Action Action Action Sample Size Result Required Result Required Result Required A minimum of C-i None N/A N/A N/A N/A S tubes per SG C-2 Plug or repair C-i None N/A N/A by sleeving defective tubes C-2 Plug or repair by and inspect an sleeving additional 2S defective tubes C-i NONE tubes in this and inspect an SG. additional 4S C-2 Plug or repair tubes inthis SG. by sleeving defective tubes.

C-3 Perform action for C-3 result-of fi rst~~sample.

C-3 Perform N/A N/A action for C-3 result of first sample.

C-3 Inspect all All other SGs None N/A N/A tubes in this C-i SG. plug or repair by sleeving Some SGs C-2 Perform N/A N/A defective tubes but no other action for and inspect 2S is C-3 C-2 result of tubes in each second other SG. sample.

Notification to NRC Additional SG Inspect all tubes pursuant to isC-3 in each SG and N/A N/A 5.7.2 plug or repair by sleeving defective tubes.

Notification to NRC pursuant to 5.7.2 N= S N/fl Y, where Nd is tnle numb~er OT Mis in tne unit and n istne nUMner OT SGs inspected during an inspection.

(continued)

SAN ONOFRE--UNIT 3 5.0-19a NOF SAN E--U IT5.O No. 1-39 7F159 1 19aAmendment

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued)

Table 5.5.2.11-2 (page 1 of 1)

Steam Generator Sleeved Tube Inspection 1st Sample Inspection 2nd Sample Inspection Sample Size J Result Action Required Result lAction Required C-1 None N.A. N.A.

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 for C-3 result C-3 of first sample.

Inspect all repaired tubes Other SG is C-1 None in this SG, A minimum of plug defective 20% of the repaired tubes, sleeves. Perform action and inspect 20%

of the sleeves S isC-2for C-2 result Othr Other SG is C-2 of first in the other sample.

SG.

C-3 Inspect all Notification to repaired tubes NRC pursuant to in both SG's 5.7.2 and plug I defective Other SG is C-3 repaired tubes.

Notification to NRC pursuant to 5.7.2 I I I I I (continued)

SAN ONOFRE--UNIT 3 5.0-19b Amendment No. +3a--159 I

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 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-accident Cleanup Filter System." 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 ANSI N510-1975 (see Note 1); 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 ANSI N510-1975 (see Note 1); and

c. Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested per the methodology of ASTM D3803-1989 at 300C and 70%

relative humidity 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.

Note 1: Sample and injection points shall be qualified per ANSI N510-1975 unless manifolds have been qualified per ASME N510-1989.

HEPA testing will be conducted with DOP aerosol or suitable alternate.

(continued)

SAN ONOFRE--UNIT 3 5 .0-19c Amendment No. +31, 178 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (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 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 G 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 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.

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 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 sleeves 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 ONOFRE--UNIT 3 5.0-30 Amendment No. 185 1

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) -

5.7.2 Special Reports (continued)

Results of SG tube inspections which fall into Category C-3 shall be reported to the NRC prior to resumption of plant operation.

This report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrence.

SAN ONOFRE--UNIT 3 5.0-31 Amendment No. 116

Attachment C (Proposed Pages)

(Redline and Strikeout)

SONGS Unit 2

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation . . . . . . . . . . . . . . . . 3.3-22 3.3.6 Engineered Safety Features Actuation System (ESFAS)

Logic and Manual Trip . . . . . . . . . . . . . 3.3-27 3.3.7 Diesel Generator (DG) -Undervoltage Start . . . . . 3.3-32 3.3.8 Containment Purge Isolation Signal (CPIS) . . . . . 3.3-35 3.3.9 Control Room Isolation Signal (CRIS) . . . . . . . 3.3-39 3.3.10 Fuel Handling Isolation Signal (FHIS) . . . . . . . 3.3-42 3.3.11 Post Accident Monitoring Instrumentation (PAMI) . . 3.3-44 3.3.12 Remote Shutdown System . . . . . . . . . . . . . . 3.3-48 3.3.13 Source Range Monitoring Channels . . . . . . . . . 3.3-51 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . 3.4-1 3.4.1 RCS DNB Pressure, Temperature, and Flow Limits . . . 3.4-1 3.4.2 RCS Minimum Temperature for Criticality . . 3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits .... 3.4-5 3.4.3.1 Pressurizer Heatup/Cooldown Limits . 3.4-13 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . .. . 3.4-15 3.4.5 RCS Loops -MODE 3 .. .3..4-16 3.4.6 RCS Loops -MODE 4. . . . 3.418 3.4.7 RCS Loops -MODE 5, Loops Filled . . . . . . . . . . 3.4-21 3.4.8 RCS Loops -MODE 5, Loops Not Filled . . . .. . . . 3.4-24 3.4.9 Pressurizer . . . . . . . . . . . . . . . . . . . . 3.4-26 3.4.10 Pressurizer Safety Valves . . . . . . . . . . . . . 3.4-28 3.4.11 Not Used 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature

2560 F . . . . . . . . 3.4-30 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 256 0 F . . . . . . . . 3.4-35 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . . . 3.4-37 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . . . . 3.4-39 3.4.15 RCS Leakage Detection Instrumentation . . . . . . . 3.4-44 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . . . . . . . . 3.5-1 3.5.1 Safety Injection Tanks (SITs) . . . . . . . . . . . 3.5-1 3.5.2 ECCS- Operating . . . . . . . . . . . . . . . . . . 3.5-4 3.5.3 ECCS -Shutdown . . . . . . . . . . . . 3.5-8 3.5.4 Refueling Water Storage Tank (RWST) . . 3.5-9 3.5.5 Trisodium Phosphate (TSP) . . . . . . . . . . . . . 3.5-11 (continued)

SAN ONOFRE--Unit 2 iii Amendment No. +24

TABLE OF CONTENTS B 3.3 INSTRUMENTATION (continued)

B 3.3.7 Diesel Generator Undervoltage Start B 3.3-126 B 3.3.8 Containment Purge Isolation Signal (CPIS) B 3.3-135 B 3.3.9 Control Room Isolation Signal (CRIS). B 3.3-145 B 3.3.10 Fuel Handling Isolation Signal (FHIS) . B 3.3-152 B 3.3.11 Post Accident Monitoring Instrumentation (PAMI) B 3.3-159 B 3.3.12 Remote Shutdown System . . . . . . . . . . . . . B 3.3-176 B 3.3.13 Source Range Monitoring Channels . . . . . . . . B 3.3-181 B 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . B 3.4-1 B 3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits

B 3.4-1 B 3.4.2 RCS Minimum Temperature for Criticality . . . .

B 3.4-7 B 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . B 3.4-9 B 3.4.4 RCS Loops- MODES 1 and 2 . . . . . . . . . . . . . B 3.4-23 B 3.4.5 RCS Loops- MODE 3 . . . . . . . . . . . . . . . . B 3.4-27 B 3.4.6 RCS Loops -MODE 4 . . . . . . . . . . . . . . .

B 3.4-31 B 3.4.7 RCS Loops- MODE 5, Loops Filled . . . . . . . .

B 3.4-36 B 3.4.8 RCS Loops -MODE 5, Loops Not Filled . . . . . . B 3.4-42 B 3.4.9 Pressurizer . . . . . . . . . . . . . . . . . . B 3.4-46 B 3.4.10 Pressurizer Safety Valves . . . . . . . . . . . B 3.4-51 B 3.4.11 Not Used B 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature s 256°F . . . . . .

B 3.4-55 B 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 256°F . . . . . . .

B 3.4-65 B 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . B 3.4-70 B 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . .

B 3.4-76 B 3.4.15 RCS Leakage Detection Instrumentation . . . . .

B 3.4-82 R-,4-RR 83.4 17 RCS. Snr2i0'civ Bg*1 33.49 3 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . B 3.5-1 B 3.5.1 Safety Injection Tanks (SITs) . . . B 3.5-1 B 3.5.2 ECCS- Operating . . . . . . . . . . B 3.5-11 B 3.5.3 ECCS -Shutdown . . . . . . B 3.5-21 B 3.5.4 Refueling Water Storage Tank (RWSi) B 3.5-24 B 3.5.5 Trisodium Phosphate (TSP) . . . . . B 3.5-30 B 3.6 CONTAINMENT SYSTEMS . . . . . . . . . . B 3.6-1 B 3.6.1 Containment . . B 3.6-1 B 3.6.2 Containment Air Locks . . . . . . . B 3.6-5 B 3.6.3 Containment Isolation Valves . . B 3.6-13 B 3.6.4 Containment Pressure. . . . . B 3.6-27 B 3.6.5 Containment Air Temperature . . . . B 3.6-30 B 3.6.6.1 Containment Spray and Cooling System B 3.6-33 B 3.6.6.2 Containment Cooling System . . . . . . . . . B 3.6-43 B 3.6.7 Hydrogen Recombiners . . . . . . . . . . . . B 3.6-48 B 3.6.8 Containment Dome Air Circulators . . . . . . B 3.6-53 (continued)

SAN ONOFRE--Unit 2 vii Amendment No. 4-24

Definitions 1.1 1.1 Definitions ENGINEERED SAFETY measurement, response time may be verified for FEATURE (ESF) RESPONSE selected components provided that the components TIME (Continued) and methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary:-

LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steamgnrar X- te SnP.9r y System t dary

b. Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c. Pressure Boundary LEAKAGE LEAKAGE (except rir ty LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

(continued)

SAN ONOFRE--UNIT 2 1.1-4 Amendment No. 4-88

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 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; Wnd

. r rE

,- f l -- e g.. I¶- - - I t - 1 - _ A

-.. I I- I --- --

- , r-i 4 , -. . -- , - V. - - - I -rr, --i A^ -I

. -, .- . ji . - l. -- . . - - . - - -j :!,L - - . -- . i .. v -.. J - ,

ULI IU ~;. UVIJ 11V L, U1JJJ I j L4IIU I . UV %;3 UFF1 I Y

d. .- ~~r~7rp-eedr LEAKAGE threugh all e.ay 2/2RRm) primary to seeendary d#.

150 gallInysper dav -rimnary to secondary LEAKAGE through any one Steam Genera, IW SG).

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure 6 i K...

AGE.,

mar..

y~

EAEA B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

OR B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Pressure boundary LEAKAGE exists.

Pr-imrV T secondary ikAGIEbot within 1lC:(

i ,i X.,Ei tS..

SAN ONOFRE--UNIT 2 3.4-37 Amendment No. 127 140

RCS Operationa 1 LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1- -------- NOTES------------------- -----NOTE------

1; Not required to be performed in MODE 3 Only required or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state to be performed operation. during steady state Perfotm anlwablter inetorya..t scn... operation.

If a transient evolution is occurring 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the last water Perform RCS water inventory balance. inventory balance, then a water inventory balance shall be performed.

within 120.

hours of the last water inventory balance 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months t

-NOTE------------

reddredK tQ be ,errorged unti I 12 hhurs ~In aeeordance fter stai ishment of steady state with the Steam itioK Generator Tu~be

.-,- Srveillne~e SR 3.4.13.2 Verify SC tube integrity is in accordance with the Stcam Cenerator Tube Surveillance VeriftY p ri iac nd>r iv LE AG i 2hurs:

<:1i50 :gallons perd i I

tIhrough anyn SeG.

SAN ONOFRE--UNIT 2 3.4-38 Amendment No. +2*

SG ube I te Aritv

.5,,j

.'00$'!:\ 17

. 3'4:'^j'.j

,$:TEM (i,,CS TOR I ANT SiYTE

. RAT COOAN 33i40:REA ' 3%S 3.4.17 .

Steam Generato ( TbIei fLC0s`3'1-.~4qT 6 tubeAbets.all b aita,ind'.

s- 2aifyn tearcrt I31 S,,tcbe iiham th asalb ro-a .- ......=- -, I I to vf'- ,

V""'4 A7M Y:

NODES i 2 , 4'and'4.X~-

I R-w.-- --

- I w4 t

tBtisr=Q theftuer =ti fte3 5 _

r3'e~

ORodac aie i'in' n outa o iibes 6SG~in tMODE afece in Aneg met .r Be nt nex maiLnta ned 5 SAN ONOFRE--UNIT 2 1.4:w511 Amendment No.

I " M '

3.417 UR LLANREQUENC R347lVrif YSOAtube integritv in ccrdnc wth _ Lrogram accordance t$tea 0e0rtr r9~~ wil;th the< "a-Generao D1jse41bleOn

~ied accodr<wthte op+ig G SAN ONOFRE--UNIT 2 3X4 52 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only until such time as a modification eliminates the post-accident piping as a potential leakage path). 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 pro ram provides controls for monitoring any tendon degradation in pre-s ressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. Program itself is relocated to the LCS.

5.5.2.10 Inservice Inspection and Testing Program This program provides controls for inservice inspection of ASME Code Class 1, 2, and 3 components and Code Class CC and MC components including applicable supports. The program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components.. The program itself is located in the LCS.

5.5.2.11 Steam Generator (SG) Tube Surveillance Program This rn , i ICUshall nleucontrols leatCt ded bei dtarmL nJ for moanitr hu OPEABL 1rn sut degiadation.

bI Iy *

'Ayn ofespecification 5.5.25.11 and by meetin1 'a MR 2U.N Re viIWsio 1, whil.h. includes at least the following;f seetigan nsatigatlas h inimum nUIII- af4"' .. C'

a. SC Sample Selettion and Inspectio n Taeh SC shall be determined OPERABLE durins HIshetin ru slectin n, and tnspeti arrt least the min nuir sa bC specified in Table 5.5.2.111 and5.5.2.11 2.

iheSGrtube inspecIAd s SevC tubes an sleees shall b es elssifieatien, and the correspondin- actin rideq ed shall b A_ speqifi

___ : _ Table_ -^ ^

Ad 9 ^ I I ^

O T C Usi..1L~ 1 1.~ SG tub. IAs- I LI&. A I 1 shall in spud

~~~~~~~~. cioa la SC the ttal

_,¢_ a- i _:_ C__s_:_o:

e J~~~--e ll1%1IC th aee CI IC Ifu

§C %I1.C IU T0

!e.e.tj1!, inpce tuephl In Ih everifiedtof 5.5.4.11.f_ The%.tube seece for each Iinserviee inspection shll. Inld at-1*5CJOVw.

les 30- qiU *hetot-a (continued)

SAN ONOFRE--UNIT 2 5.0-13 Amendment No. 147,168,178

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) enI~e~thtS&ue rtecrt -W nAihtai ned ~In MdBiiol th e Se'am an dI .i.t ae ent C iti

,ge, codu:,asepmeti~el

a. o Ihen ana t -iothe ound ilakcnie.Th : si oin niefr'Siamtoo cidstono t gne~f9 in~ctdW esu: j0aloPl fms orediorto o-f;:~GtutbeWiteai XWSdty dstaet5tU1 toga IXS de 6ttu5(

r--Mj p't~eon rutue termne fo pe!fptemn teiabthe ite sicenes-met (continued)

SAN ONOFRE--UNIT 2 5.0-134 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SC) Tube Surveillance Program (continued) number of tubes in all Ss; the tubes slected for these inspections shall be selected on a random basis except.

1. Where xperince in simcitlar Plants ith similar water then atL ea~s ju% of the tubes inspected shal b froAm the critical areas;

2. The first sample of tubes selected for each inservice ction subsequent to the preservice inspection) of SG shalld _

a) All non repaired tubes that previously had dctctbl ha 0)

!alpnertonygeae b) Tubes in those areas where experience has indicated potential problems, and c) A inspection, t l bersuant (is trecrfded and n

4. olloing het eths siall be cionrded and an adjacent tuhl be spacte selected and subjected to a tube

3. All sleeves shal.l be isected woith eddy current prior to initl tion. h inlue pe . reta1ining petHRR ACd h_ _the. lee .. -...

IurLi iandom s ebaion. v f ndctn and

. ,,, p,,su r retas fderdtnaefod W,,

ptnof the sleeve.

r la.: A : x. _ :_ Id o. Aml-- 1 that ha ve bee ~in rice

.. for a suit cyleooeato shsall be inpced. The sleeves shall be slcte o rado bsi. f i.ndicatioens of degradation ar foundm in the sampa t heinspection sample shal b4 e expanded.

T.H._ 9 f asr~. :_

ant__4 e_ _1 (continued)

SAN ONOFRE--UNIT 2 5.0-14 Amendment No. 127 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Survei.lancee"IProgram (continued) with a~dsafelv ador tof ltZon the-scombi ned prmar~y 4 secndav~ acidj~hi~di 6&iakirteXr vri~V

~ny bavs

~ ccien.~ohe ~hi~SG ub AWtrA a jo~~ke~ ~~ ~ai ateasmdi offcjrai, ehi~rt~1 aaert

~s leak~EE

~~ and rate

~Vj dViul G rr

~O~ ~pn ~t$G d;I fri toecee The~onratona LEKAG nef~ra~1~i~~jtrio~d pfsevc insecio to3ntj flweT eoh 1,i Acvientindued e~kae ~e~-frm~ ~rit (on:thned otIonoffi v-t-ti4wed Proviionsfor~G~bei~nectQns(Pernotcnuetub SAN ONOFRE--UNIT 2 5.0-142 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerator (SC) Tube Surveillanee Program (continued)

c. Examination Results The results of eaeh sap ... iF nspctin shall be classified into one of the following three categeries.

C 1 Less than 5$% of the total tubes inspected are degraded tubes and non: ef the inspected tue aedcetic C2 One or more tubes, but not more than 1%k of the total tubes isected are defeetive, or between 5% and 10%W of the tta ubsinspected are degraded tubes.

C3 More than 10° of the total tubes inspeted are degraded tubes or mare than 1% of the inspected tu.es a-re This elassificatien shall also apply to sample inspections af sleeves.~

- N~OTE in all n, peiuy dc_radcd n:n rep red. tu-es mw.ust ex I ibit sgnifiant (greater than 0%) frthe wall peerainst he includ~ed in tc aboe rerentage

d. Supplemental Sampling Requirementsr The tubes selected as the seeand and third sampleqi reurdb able 5.5.21 1)mybe sujete tA Apatl Te -n s pei _n

- rvided:

1. The tubes selected for these samTlce include the tubes fram1 these areas of the tube se ar where tubes with imperfeetiens wereprvusyfnd ad

2. The inspectians einlude raded p on-rens af the tubes where mcfcin eepeiul faund.

(conti nued)

SAN ONOFRE--UNIT 2 5.0-15 Amendment No. 127 140 8/,6/98

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) toensure thiat SG tub in,,teciritv is, maintained~untlth nex SG, insoection. A sssmen of dearadation shall be nerformed to :determine the tvDe and location of!flaws to which thetubes mav be susceotibl:e and. based, on thist assessment. to determine which inspection methods need to be employe dand at what locations.

1X. nsect 100% o the tubes in, each SG duri ngthe fir refueling outagefofllowing SG replacement.

. st otuad sleevet 1 seauen ial te i ns rvc iseton ofthe .b.SGs` S Nof all one refuelingout'age (whichever i~sless) withou bin inpec.

3 Ifcakindicatios ae found inayS-ub.te h next inspection for each SG fothe de-rada'ti-on.

mechan sm .causd the k iicatio shall exed2pefcie ulnwer,Montso oe frefuelind outaae (whiche er is ss). If defin tive iTnformatlon, such as from examinati on 'of a Duiled: tube. diaanostic non-destructive test~inab or enciineerina evaluation indica~tes tat a cra£ck-like indicatitonisnot associated wWi thla crackis), then the indeication need not be treated as- a~tcrack.

r sins f rin operatio pimary tosecnary LWEAGE.

f Provisin fo Gtb earmtos ta eeao ube reo~air metofds shall "4ro0'vide temans to r6e-es'tablish'th'eRs or~essure bonayi tevi ;of `SGItubes,~withdot remoVio -the,.

tub frmsrvc. Fo h uroos~es of ,thes Sn fcTions, tube .lnain r i o pair. All ac ep ita tue repair methods are .li stead,: below.

(conti nued)

SAN ONOFRE--UNIT 2 5.0-15a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerator (SC) Tube Surveillance Program (continued)

e. inspectian Frequeney The above required inservic inspections of the non repaired Sc tubes shall 1, pa fered at a1 _ g requ i es; f llawi.

1. The first inservice inspection t~~~~4 LA AA4.11

^A I shall be _ performed f!! 1 after Ceffective full pawarmats u wuithi 2 calendar months of il criically. Subsqn *,rac inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the pr !cs inpaion. if two eescuiansepections,

. i.ncluie preservi:e in4p etian, re.ult i, all inspections results falling into the C-1 category or if two consecutive

-A A- A.A. -_-

inspections

'~ a, A,_!

demonstrate that previously ertad degradatian has ntccnurred the inspetion ineral mfay 3e extended to a maximu ofoneer4

,..l. . . -, ,

2. If the results of the inservice inspeciton ef a SC cendueted in aeerdance with Table 5.5.2.11-1 at 40 manth intervals fall in Cateary Cth i enseatiaen shall be increased toatmaxim af easpt 4e ns,0 t The

_ q . kA{fiAtAAfiA_;.ts- A AmeA_ _A

3. Additianal, unspheduled isptn shall be II fr. TVTT .J. Sned a IIT.C1 i U TcIIIdJ t firiSt sampla inspection specified in Table 5.5.2.11 1 during the shutdown subsequent to any of the following een-~-

a) Primary-to secondary tubes leak (not including leaks riginating from tube to tube sheet welds) in execss Af the limits of Technical epecificatian b) A seismic accurrenee greater than the Operating Basis Earthquake, ev-e) A lass -f -colant accident requiring actuatian of the Engineered Safety Features, or d) A main steam line or feedwater line break.

(continued)

SAN ONOFRE--UNIT 2 5.0-16 Amendment No. 27T 14 O8/26j98

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube SurveillanceezProgram (continued)

_SDrI ~E-3-~Rv ,i urnl prvdby the NRCE.w (continued)

SAN ONOFRE--UNIT 2 5.0-16a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerator (SC) Tube Surveillance Program (continued)

4. Th rf Tehnical Se fi....ations Surveillan.e Requirement 3.0.2 are applicable to SC Tube Surveillance inspection frequencies except those

_stablishe b1 Catgr C iI r esuts.

The above required inservice inspections of SC tubes repaired by sleeving shall be performed at the following frequencies.

1. Steam generator tube sleeves shall be inspectedDrior to initial operation and in service. The initia opraiper erodbefore the initial isriesml inspectin halnot be shorter thans- mnh o I t 2 mnths. The i ions of sleeves Ih, becniured to enur ta echidvdual Ilev -Is inspeeted at least once inf0mots

2. If the results of the inservice inspection of SC tube sleeves conducted in accordance woit Tabe 9.5.2-11 2 fl in cA t in tio Ar shall be increased to ensure that each remaining sleeve is inspected at least once in 30 months. The increase in inspetion frequncyshalla y ,unti the subs q .1e1 At_

inspeetions Tlla~4SIVIal stfI~

a"Ul~a thl criteriaw W1juf~~U,1u IU"w r Categ U~ol 1.

r Cusvlyv f. Acceptance Criteria

1. Terms as used in this specification will be defined as fellows; a) Degradation A service indueed eracking, wast age, wcar, or general corrosion occurring on either inside or outside of a tube, b) Derddtbe A tube containing imperfections greater than or equal to 20% of the nominal wall thickness cause by degradation; c) %egrdatin Te pecenageof the tube wall1 thickness affected or removed by degradation, d) Defect An imperfection of such severity that it exceeds the e p air limi. A b n defectX is w11 J-UlvI defective.

s I 11. . r usv l~ Ir l (continued)

SAN ONOFRE--UNIT 2 5.0-17 Amendment No. 12 14O U/-26I98

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SC) Tube Surveillance Program (continued) e) Imperfection An ex eption to the dimensions, I Il1ralf, V' UUItIUr of - tube fIrm that lTI furren ttion Aini n i ow 20o of the nominal tube wall thickness, if detectable, may be considered as imperfetiolns, f) RearLmt The imefcindpha qr beyond which the tube shall be removed from service or 1 ~~t ~ ~ ~ - f4 tou 70 of th IU,3sufC 1 nemluial, tlu be wall thckne ..

Seeves shall be removed from services upn detection of service induced degradation of the sleeve material or any portion Vf the sleev t t--ub wel d.

g) Preservie Ise p* ¶stio ;rr Aninlspeetien of the ll ee......I.. 1.11 full'u

_llT~rfl~ _5- rfa n p. Vrfrw : _:_A_:__1 A _. L - II T.6 Lu u baelnecodition of the tUbi . This . ins.QAp ect ion

. IR :_ I: 1 *Inr 1 L

aluI ~LII u - U 1 SI I U u I If V I 1 C z U uU I .WU f

operating using the equipment and techniques expected tV bc used during Su uent inservice for tube repair by sleeving, an inspection of the the sleeved area shall be performed by eddy icudeJ tenure efi. prior tosrvice .e this

.." z-1..4 tube weld, and the pressure retaining portion of the- seeve .

Tue Ipcl h) lf A 1l thotion An

~~~- _ _1

..@r

+Zl_

o2 -

f the SG tube hri ~ ein ef e~nt i *h"t~

tubehee (T) blow5 inches from the secondary i) Unserviceable The condition of a tube if it leaks or contains a defect large enough to affect its strutural i t in t e o ..

Operational Gasis Earthqluake, a loss^-ofcoolant acdnor a steam line offewae ine break accident as specified in Specification 5.5.2.11.e.

This exclusion is for Unit 2, Cycle 12 operation only.

(continued)

SAN ONOFRE UNIT 2 5.0 18 Amendment No. 189

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 4 5.5.2' Steam Cenerater f (SC) Tube Surveill ance Program (continued) j) Tube Repair -refers to a process that reI~ U t+/---tIJ; tUbe-ervCeab UUIlIty-. AUCccptaIle tube repairs will be performed by the fo lowing TIr welded sleving as described in ABIrr T_ _pa Report, C[N-630-P. Rev. 2, is currently approved Tube repair includcs the allatvon by wei--

of thesl-eeves, heat treatment in accordance with CE-30P Rev. 2, to reov te st-resses that are

,introduced brteseeeisalain eceptance examination for futue comparison. Tube repair AUl can e prformed on !!eritain. tubes that have Ibccn IIIU ,USOil I ISUV I l U I. s U UU! ITpar Unl prvosypu das a corrective or -neventive thervice.salb

.II . AL p Il - LU efre II napeiul I5 I

2. The SC shall be determined OPERABLE after completing thexcoding ttaini 1.. LL V ll.W I 2 III IL I ,U IL% I J-h _UI

5. .2-11 1 rai criteria) 2 q.uired by Tables

.J.J.. l-sU..U .5.2.H *--.

9. Reports The content and frequency of written reports shall be in aecordance witI echnI - ,pec fiato I 5.7.2, "Speci.dal Reperts.

(continued)

SAN ONOFRE UNIT 2 5.0 19 Amendment No. 127 140

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerater Tube Surveillance Prrgram TABLE 5.5.2.11 1 (page 1 of 1)

SUPPLEMENTAL SAMPLING REQUIREMENTS S - 3 N/n

,- Where N is the number of SCs in the u"i*t and nF is the number of SGs inspected during an inspection.

(continued)

SAN ONOFRE UNIT 2 5.0 19a Amendment No. 147,168

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals"-( (continued) 5.5.2.11 Steam Cenerator Tube Surveillance Program '(continued)

Tab _f.5 2 (page 1 1)

Steam Generator Sleeved Tube Inspection I p!e54z 1st Sample Inspection I Reul C-i Aeti

e0

'n 2ffd Sample Inspeetion ftesqulredjActian N.A.

Rqie A.7 Plutg-defeetive ta repaie tubes ee ad inpect Plug defective, 1%oth Cf epaired tubes.

C-t sleeves in this a aca_

er Pfeform action C-3 for C-3 result

-; of first

- sampe .

+nspeet-e-l-+

repaired-+tubes Other SC is C 1 A minitnum of 2% of the.

s! eeves. Perform action of the sleeves Other SC is C-, for C 2 result OC f *first SGT "mffp4e-.

C-3 inspeet a4-I Notification te rpied-+tubes NRC pursuant to Other SC is C 3 repafrId tubes.

Netifitatin tS' NRC pursuan ta 1_q. .

I I I i.

(continued)

SAN ONOFRE UNIT 2 5.0 19b Amendment No. 140,168

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerator Tube Surveillance Program (continued) 5.5.2.11.1 The inservice inspection may be limited to one SC on a rotating schedule encompassing 696 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 SC may be found to be more severe than those in the other SG. Under sueh eireumstances the sample sequenee shall be modified to inspect the most severe conditions.

5.5.2.11.2 The other SC 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." 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 ANSI N510-1975 (see Note 1); 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 ANSI N510-1975 (see Note 1); and

c. Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested per the methodology of ASTM D3803-1989 at 30'C and 70%

relative humidity 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.

Note 1: Sample and injection points shall be qualified per ANSI N510-1975 unless manifolds have been qualified per ASME N510-1989.

HEPA testing will be conducted with DOP aerosol or suitable alternate.

(continued)

SAN ONOFRE--UNIT 2 5.0-19c Amendment No. 140, 187

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 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 G 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 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.

Ca . ee: inse ten e_ t;8^~_Aerb(G SG SurveillYanceeP4I.

tubesJ, tlo -iinh- N accrdnc yIa with.ithe_

'ivrnl __f TubeJ R~- _--1ihn

_'t#A- _r ArAL i i ro LLT Vpu

lII~

b.e-reported I LUU,I1 to thqe uyw~

LaffU Cwihn1da~ys. CUU9 a1. Te w. vu complte resultsilJV3 I

fQu,..

af the eC tube inservice inspection shall be submitted to the RCwithin 12 m"nhsfalaing th coPAletPi8n ef the in etien. The repeart h i:I cI _ ...

1. Number and extentAf tubes and l inspeeted, and

2. Location and pcrcent of wall thickness penetratien for each indication of an imperfection, and J. _IdtI IqaIW A report Tsh be tut alli within

~qe ndtbsscv W "

_1, Esumit tf the iieh ati e ne .2 nih To , Steam rTCl ctuude:

(conti nued)

SAN ONOFRE--UNIT 2 5.0-30 Amendment No. +94

Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Special Reports (continued)

Results of SC tube inspections which fall into Category C 3 shall be reported to the NRC prior to resumption of plant operation. This report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prcvenpt reeurrenee. W ACscopeB nset A abe foX . A SGAd regra -aii 3odJfor ech M oMtion MI b iettio{¶ inr)*N ind esird ies at-t i 2-:.x ff`

"Mh~efetv M1qqj, 4, pr entg f~1 ~gi rin-=chq =-

E =@_ Reiai mehduizdanwenrne f ie eard SAN ONOFRE--UNIT 2 5.0-31 Amendment No. +&

Attachment D (Proposed Pages)

(Redline and Strikeout)

SONGS Unit 3

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation . ...... .... 3.3-22 3.3.6 Engineered Safety Features Actuation System (ESFAS)

Logic and Manual Trip . . . . . . . . . . . . . 3.3-27 3.3.7 Diesel Generator (DG) -Undervoltage Start . . . . .

3.3-32 3.3.8 Containment Purge Isolation Signal (CPIS) . . . . . 3.3-35 3.3.9 Control Room Isolation Signal (CRIS) . . . . . . . 3.3-39 3.3.10 Fuel Handling Isolation Signal (FHIS) . . . . . . . 3.3-42 3.3.11 Post Accident Monitoring Instrumentation (PAMI) 3.3-44 3.3.12 Remote Shutdown System . . . . . . . . . . . . . . 3.3-48 3.3.13 Source Range Monitoring Channels . . . . . . . . . 3.3-51 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . 3.4-1 3.4.1 RCS DNB Pressure, Temperature, and Flow Limits . . . . . . . . . . . . . . . . . . . . . 3.4-1 3.4.2 RCS Minimum Temperature for Criticality . . . . . . 3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . . . 3.4-5 3.4.3.1 Pressurizer Heatup/Cooldown Limits . . . . . . . . . 3.4-13 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . . . . . 3.4-15 3.4.5 RCS Loops -MODE 3 .. 3.4-16 3.4.6 RCS Loops -MODE 4.. . . . 3.4-18 3.4.7 RCS Loops -MODE 5, Loops Filled . . . . . . . . . . 3.4-21 3.4.8 RCS Loops -MODE 5, Loops Not Filled . . . . . . . . 3.4-24 3.4.9 Pressurizer . . . . . . . . . . . . . . . . . . . . 3.4-26 3.4.10 Pressurizer Safety Valves . . . . . . . . . . . . . 3.4-28 3.4.11 Not Used 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature

246 0F . . . . . . . . 3.4-30 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 2460F . . . . . . . . 3.4-35 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . . . 3.4-37 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . . . . 3.4-39 3.4.15 RCS Leakage Detection Instrumentation . . . . . . . 3.4-44 Sneifi 3A..6 ~ Mtiitv . ,,,~., ~ ~. . 4-47 3.4.17~flu~ltn

!WSt Sta Geeao Tubet Inert tSG 34 5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . . . . . . . . 3.5-1 3.5.1 Safety Injection Tanks (SITs) . . . . . . . . . . . 3.5-1 3.5.2 ECCS -Operating . . . . . . . . . . . . . . . . . . 3.5-4 3.5.3 ECCS -Shutdown . . . . . . . . . . . . . . . . . . . 3.5-8 3.5.4 Refueling Water Storage Tank (RWST) . . . .. . . . 3.5-9 3.5.5 Trisodium Phosphate (TSP) . . . . . . . . . . . . . 3.5-11 (continued)

SAN ONOFRE--Unit 3 111 Amendment No. +*

TABLE OF CONTENTS B 3.3 INSTRUMENTATION (continued)

B 3.3.7 Diesel Generator Undervoltage Start . . . . . . B 3.3-126 B 3.3.8 Containment Purge Isolation Signal (CPIS) . . . B 3.3-135 B 3.3.9 Control Room Isolation Signal (CRIS) . . . . . . B 3.3-145 B 3.3.10 Fuel Handling Isolation Signal (FHIS) . . . . . B 3.3-152 B 3.3.11 Post Accident Monitoring Instrumentation (PAMI) B 3.3-159 B 3.3.12 Remote Shutdown System . . . . . . . . . . . . . B 3.3-176 B 3.3.13 Source Range Monitoring Channels . . . . . . . . B 3.3-181 B 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . B 3.4-1 B 3.4.1 RCS DNB (Pressure, Temperature, and Flow) Limits B 3.4-1 B 3.4.2 RCS Minimum Temperature for Criticality . . . . B 3.4-7 B 3.4.3 RCS Pressure and Temperature (P/T) Limits . . . B 3.4-9 B 3.4.4 RCS Loops -MODES 1 and 2 . . . . . . . . . . . . B 3.4-23 B 3.4.5 RCS Loops- MODE 3 . . . . . . . . . . . . . . . B 3.4-27 B 3.4.6 RCS Loops -MODE 4 . . . . . . . . . . . . . . . B 3.4-31 B 3.4.7 RCS Loops -MODE 5, Loops Filled . . . . . . . . B 3.4-36 B 3.4.8 RCS Loops -MODE 5, Loops Not Filled . . . . . . B 3.4-42 B 3.4.9 Pressurizer . . . . . . . . . . . . . . . . . . B 3.4-46 B 3.4.10 Pressurizer Safety Valves . . . . . . . . . . . B 3.4-51 B 3.4.11 Not Used B 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature s 246°F . . . . . . B 3.4-55 B 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 246°F . . . . . . . B 3.4-65 B 3.4.13 RCS Operational LEAKAGE . . . . . . . . . . . . B 3.4-70 B 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage . . . B 3.4-76 B 3.4.15 RCS Leakage Detection Instrumentation . . . . . B 3.4-82 R 3.=4A61§c B 34-P.R 1B 3.4.170 =

RC.S Sneifi r Activity B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) B 3.5-1 B 3.5.1 Safety Injection Tanks (SITs) . . . B 3.5-1 B 3.5.2 ECCS -Operating . . . . . . . . . . B 3.5-11 B 3.5.3 ECCS -Shutdown. B 3.5-21 B 3.5.4 Refueling Water Storage Tank (RWST) B 3.5-24 B 3.5.5 Trisodium Phosphate (TSP) . . . . . B 3.5-30 B 3.6 CONTAINMENT SYSTEMS . . . . . . . . . . . . . . B 3.6-1 B 3.6.1 Containment . . . . . . . . . . . . . . . B 3.6-1 B 3.6.2 Containment Air Locks . . . . . . . . . . . B 3.6-5 B 3.6.3 Containment Isolation Valves . . . . B 3.6-13 B 3.6.4 Containment Pressure . . . . . . . . B 3.6-27 B 3.6.5 Containment Air Temperature . . . . B 3.6-30 B 3.6.6.1 Containment Spray and Cooling System B 3.6-33 B 3.6.6.2 Containment Cooling System . . . . . B 3.6-43 B 3.6.7 Hydrogen Recombiners . . . . . . . . . . . . B 3.6-48 B 3.6.8 Containment Dome Air Circulators . . . . . . B 3.6-53 (continued)

SAN ONOFRE--Unit 3 vii Amendment No. +16

Definitions 1.1 1.1 Definitions ENGINEERED SAFETY measurement, response time may be verified for FEATURE (ESF) RESPONSE selected components provided that the components TIME (Continued) and methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RgS) LEAKAGE through a steam genpratnmr #R-,-- the.

Serondary System

b. Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c. Pressure Boundary LEAKAGE LEAKAGE (except &GV;rto ondary LEAKAGE) through a noniso able fault in an RCS component body, pipe wall, or vessel wall.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

(continued)

SAN ONOFRE--UNIT 3 1.1-4 Amendment No. 4-16

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 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; and z~~n-rr 1.l - d, ~^ 1 _ : : I - 1 1 - j rl as _ - - - I. . _

ll-----

- N------- --- - ln -- zn rn -iTlr

-r l_

. - . .. . . i g... l.il 1IIYVL. .2,! ,VzH Y ln--

-: t

nv .. t%1,

'.1. r- _

IInl-5 Inwinel

.- I.J%0 .. Ile U, l.eTlnn lels+.^I nT I It I. I WI I jW1 UI1J - clP"vinn rnv " 1`Iv4'IV~ Oil uIjr A ~IU, U .

WMI C. UJ) MMJI U1JjJI Lm T. dve5 uppjj.

R.RMal m"tqecndrYLEKAGE through all C. WP A , fl primary to seeafndary I

df. l ....

~, u 150rgi.@ gall'1'- z eni"I,-'

xz.,w...,w

.wE

¶

!u,gi

'mryro 11 secondary LEAK'AGEthrough any one Sta Geertor1 Su).

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS raton A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure boundary LEAKAGE or rimary to0 seclondary LEA=KAGE.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

Primary to secondary LEAKAGE not'within limit.

SAN ONOFRE--UNIT 3 3.4-37 Amendment No. +/-16-432

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ----------------- NOTE"-------------------- ----- NOTE------

Not required to be performed in MODE 3 Only required or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state to be performed operation. during steady state operation.

LEAKAGE If a transient evolution is occurring 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the last water Perform RCS water inventory balance. inventory balance, then a water inventory balance shall be performed.

within 120 hours0.00139 days 0.0333 hours 1.984127e-4 weeks 4.566e-5 months of the last water inventory balance 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months MIWW7 PauN 1" flt aiird0tW t diS ined titl 12 h3urs in eeearancee with the Steam bfttab~~mf~~ tedy Qst..,,,,=.,...!

at.--. e -- Generator Tube Surveil11ancee verity SG tube integrity is in r aeeerdance SR 3.4.13.2

^ . .

- r tL 1 t -

tu L --

A

. 2Progrsm f . I arV.. t

~ecn~ay LAp(GE fis dathTI 470nyorES SAN ONOFRE--UNIT 3 3.4-38 Amendment No. +%

SG ,Tub e' -I ntr Itv R i1.4. -

3'.'4 'REACTOR COOLANT ISYSTEM (IRC 3.4 17 eahi Geneat~o,,r;SG). Tu~be rit L.~ 34 A SG b aintgiysaiberanan All SG"uess satsffy-fini _ NW...

thei'K'Titbereaf fhO citri sawe tjd 'l rep' n a iGnea PpLCAB iJTY, M MOOFDallas ", 2 il032E11,11

-11 A-,,I,,,,,----

fi 11

- , "M,-

11 MV.,

Ifi A 1

x - 4 I'l W, oatiti6n rv lsjaTwed for eaCiySG' tu&e ;*

K' hfNojiN ~EU1RED ACtIO' 7~MWEION ~

P~tatiefThOth (ub p te af e c~~'ttr

~~ep~l+ n u~~iana~

._. . ?1 Amendment No.

SAN ONOFRE--UNIT 3

SG Tube Intporitv v i0 t! ;3.4.17 SIRVEI lqAw~~Et!~4NT ________

UVEI LIANCE rRQUNCY j7 e Steam Generato arooram ~iht eSta rarmgeam SAN ONOFRE--UNIT 3 3Ill. t1 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only until such time as a modification eliminates the post-accident piping as a potential leakage path). The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. Program itself is relocated to the LCS.

5.5.2.10 Inservice Inspection and Testing Program This rogram provides controls for inservice inspection of ASME Code Class 1, 2, and 3 components and Code Class CC and MC components including applicable sup orts. The program provides; controls for inservice testing of ASME Code Class 1, 2, and 3 components. Program itself is located in the LCS.

5.5.2.11 Steam Generator (SG) Tube Survcillanee, prrls - 'de- for mernIn r._ :_hn

_ r V -tien.

1.83, Revisin 1, which includes at least the following;

a. SC Sample Selection and Inspection Earh SG shall be determined OPERABLE UrI hta by selecting and inspecting at least the minimum number of SC

__,ICIfI in 1 1 Ta1 S 2 11 a1n .52 .11 2.

b. SC Tube Sample Selection and Inspection The SC tube and sleeve minimum sample size, inspccticn eut . .sfiate, an th ee P , - i P-..

shall be as specified in Tab!e5521- r se 1

'P.

an 5...12 k - - ~~A-11 The inser andh e ef SC tubes and sleeves shall be rspectien inspedtan the inclepata ea inra of thetift ation h ueoted for eanh inser

_fspe n-s inlu at lea X@1l 3; of

.st 43 6 .

(continued)

SAN ONOFRE--UNIT 3 5.0-13 Amendment No. 139,15 9 ,169

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued)

A Steam GeneratorProram shall be establisd andimD emented to ensure that ,'SGtubeinteritv is maintained.0In .addition, the Steam Generator Program shall include the following provisions:

a Provisions' for condition monitorino asset Conditio mnitoh rino asOsess ment .means anevaluatio o e "s found condition o the tubi no resoect topec the: n-erformance critera for, stuctural: :intedrjitv and accide i duc eka.Te, "as foun~d", condition refers toi the codition ofa the tubino durina an SG insbection outae. as mined f om the"inservice ijnsoection result5s or bYother,; meapns. orior to the 6, Iuaian a r roaireb of, tu0 befst, Condition mitorine assessments sihallVbe' conducteddurino )each:outaedurinawhich t SG tubesnare infsected. Dlued or rei rd to confir that the performance c,.criteria are being met.

b,, P criteriaintriv S tube ite shalrlbe.mainained by'meetihna the eorfo.rmanc,;criterafor tube,'structural I"integr~ity,o acci dent .inducedleakage, and o'pe'rationalLEAKAGE.

-. Structural .gin.tear :Alleo ecrit

-it erion: n iz00l-4 servic steam ne j~*=g(ter ortbs orake, sal X, -retain~strucua ilnteurit over thefulsl ranue'of norma } ertin condiltiions Hincldin sntartu. aoaerattion inthe owwer rane.d 'hot standby, andS cool down0and a,ll' ajntic iated transientsincluded in the desian s Tecificaton) and desion basiis4accaidents. Thi includes retaino a safety factor -of3.0 0 aaainst bu'rst unde'r" nohrmal'steady state fUl, oower oneration rimary-, e, on darv pressure di fferenti al:: and a safetyfator of .

aainst b urst 1anoied-to he desi'nbasi tsacide t orimarv- to-secondarv tressure differential s. Apart frmthe above: requ'irements a"di ional oadino, conditions associated with the des(in basis accidents, orscombinati~on of accidents n accordantce Wit the desion and lie~ensina basis. shall :alsobe evaluated to determine tifthe associated'Jlo'adsc6ontr bute sianifica~nttlv.to burst or collanse=In the assessment of tu be intearitv. those load s:that do sianificantly affect burst:or collapse'sh all 'be determined and (continued)

SAN ONOFRE--UNIT 3 5.0-13a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.1 Steam Generator (SG) Tube Sirveillanee PrAgram (eenti'^ed) number of tubes in all SC;, the tubes selected for these inspectians shall be selected on a random basis except.

1. Where experience in similar plants with similar water ems _ o ateX+.s _ri to be _ eeted, _s thenatleast 0 of t he tubes inspected s from the critical areas,

2. The first sample of tubes selected for each inservice inspection (subsequent to the preservice inspection) of each SC shall Include.

a)All non-repaired tubes that previously had detet-abu, wa,,cttrtin (greateru 20%)fiv than~s b)Tubes in these areas where experience has indicated potential problems, and c)A tube inspection (pursuant t pecificatien 5.5.2.11.f) shall be perfarmed an each selected tube.

Tf an selected

. tueIRe nat mit the Ap__a__Af the eddy current probe far a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tubeineti.

3. All sleeves shall be inspected with eddy current prior to initial operation. This includes pressure retaininipartias f th_ p n tub i; t with the s le., the sleeve tA tube weld and the pressure retaining portion of the sleeve.

4. Fallewn h prsri U inspectia~n 20% af sleeves that have been in service far a full cycle of

-p--aiAn shall b inspced. The se s.all be seecedataradm ass If ndiatians of degradatian are found in the sample the inspection sample shall be expanded. Table 5.5.2.11-2 contains the requirements far sample expansion.

(continued)

SAN ONOFRE--UNIT 3 5.0-14 Amendment No. 116 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveiliance Program (continued) assessed incobnaion wit tahe lads pressure a saf with factr-od .2o the cmbne ty pimr loadstand 1.0 on axial secondary loads.

2. Accident 0nduc k leaa erformance cri rion: The riay to econd" acdent. induc'ed eka ,aryi rt e o any desicin b a d oher than-a SG tube, ruture. shal not excedth lekae ate jassulmed -in' t ac~c1ident an alsisVin4 erms of totla leakaqerate for all SGsG and leakace rate for an i ndivid ual S.

Leakace is not toiexceed 0.5 gpm perSO a-nd 1 gpm throug bth' SGS.

3. The perationlb"Aa LEAKAGE erforance ciriterion s pecified ineLCO 34.3, j',RC O Ol LEAGE."

c. rov1isions nSpeO fo tub rearcieia ue on rb eceedinci4%o the nominl tb altikessalb plugjged or repaiTred.

Sl4eieves shl ereoe6ro evc 16odetection of s&vice-induced ecradation of the sle veimatera l or any portion of t -e sleeve-to-tubewelbd.

d. Pro~vi sionsfrS ueisetos Priobdic-`SG tube the tubetsinsoected and methods ofsinspection shall be tueto-t u~eshe tfwedl dtaiubt t tub ..le to mh $tube-to appbl icabl e tub ir~oi~r c:iter a. l::ihe tuibe*-to-td'hee weld1 is noirtm of th tube* dl ni~dd t o o meeijth ins~pectilon methodfs, tand inspection; intervals shaillg be ~suc ;as (conti nued) 14.

SAN ONOFRE--UNIT 3 5.0-14a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued)

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 defeetive.

C-2 One or more tubes, but not more than 1V of the total tubes inspected are defeetive, or between . and 1n of the total tubes inspected are degraded tubcuus.

C3 More than 10% of the total tubes ir pe ted are Ai -- A _ L - X l0

_ 1 .

in A --- -- - - A -U - -

-. ,---S are defective.

This classification shall also apply to sample inspections

-NOTE iT all 1nspeetions, previously degraded non repaired tubes must exhibit significant (greater than 10%) further wall penetrations to be included in the above percentage callul atiens.

d. Supplemen tal 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 thre tubes from those areas of the tube sheet array where tubes with imperfections were pretiously found, and 2.-The-4nspeeti include the se-portios-o- thp twhpq ons wh~ere imperfections weePT 4 (continued)

SAN ONOFRE--UNIT 3 5.0-15 Amendment No. 116 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillance Program (continued) to' :ensurethAt`SG tbe inteor is mintane uintil the next S- siflSectiOn. An assessment of rdeqradatin shall be nerformed t ne the tvn 0odetermi e and locaion 6flflaws to which the tu bes maybeisusce tibale and based oni this assessment, to determinehwhich inspection mebthodss need. to be employed and; at what locations.-

Insct 00% Of the, inec SGtduring;th ttube e rst refulin otage fooIn 6relcmnt.

on e reueingo hever Is less)wit h being inspetd of 60efective full

.perioeds2 nower mo~nths. Th firstul

3. If crackin ti PAr fNoun in any SG tube,then the hextn nspefctio or Ieach SG, for thederradration medcanism that cad t he crkindicationsh not oexee24 effectiv ful noeeoth roe euln not be treated as aicirack.:

e r sionsfr itomn oper onaol rimar LEAKAGE.

f Provisio tu emet ods Steam generator tE repaifr methodsi shll provlide the; eans to re-stblsh h C press~ur &boundar i ;ntecqritv ofS(tubesLwithut rev the=

tu'befrom serviuce. For tehCe urnoses ap f ations t Iuibetleuiiniisnot dareipair.i Alldacceptable tube repair methoads sare e do wl eist :below.d (continued)

S O35A e SAN ONOFRE--UNIT 3 5.0-15a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG) Tube Surveillanee Program (eontinued)

e. Inspectian Frequeny ta.l II O"aSWI b>U Forme The above reaquircd inserviee- inspeetions of the men repaired SC tubes shall be performed at t e fallowing frequencies.

1. The first inservice inspection shall be performed after 6 effective full power months but within 24 calendar months of initial critically. Subsequant inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the pravousinsectan. if two eanseeutive inspections, napI nludngt I V ~ UlJ prescUrvic

[I"11,Uit U.Ne IJk II rwasultbinllUkIls WUC1 UI inpetin wIVVI U[

VII.

I IIspctivan result alln f int th T C 1u caegr yvJvoryifs tw )anseeutive in!!speeans demanstrate that previusly observed degradatian h na _cantIned and ma additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 fInefihst,

2. If the results of the inservice inspection of a&SC eendueted in accardanee with Table 5.5.2.11-1 at,401 month intervals fall in Category C

__.I.1A+_X~t.0tSI___ .e.:'IPq 1 3, the

_rr QhP_ 14œ inspectfon shllb in-reTse to at leas ere Thfl

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y1 U _1,- I _I __ _g untl v *__a1_s_

I" Ij TWI _bon the iihi'"nten h-v trfw a' P-t'-i -f extnde ta a maxiu eo nee per 40 months; &nd

- 3.

. Additinal, unschduled Adtinl nshdld s nevc insecton shall sal be b performed on each SC 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 seeendary tubes leak (net fneludi:n lea s -ctube ritinating from tube t sheeit welds) in excass af' the limits af Teehnical Speeifieation 3.4. 13, _

b) A seismic aecurrenee greater than the Operating oBa.,is Ear thquake, or c) A lass of coolant accident requiring actuation of the Engineered Safety Features, or m,1n r .- .... -

(continued)

SAN ONOFRE--UNIT 3 5.0-16 Amendment No. l6l 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued)

V.

5.5.2.11 Steam Generator (SG) Tube SurveillanceeNProgram (continued)

NRCi.

klev X e~ treatenti codaewth CEN-63O-WP (continued)

SAN ONOFRE--UNIT 3 5.0-16oA Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerator (SG) Tube Surveillance Program (continued)

4. The provisions of Technical Spe.efications Surveillance Requirement 3.0.2 are applicable to SC Tube Surveillance inSP act. in frcqunci-ees exa W t these establishelud by Ira V -UCat

.Jinse t I reulta.

The above req~uircd inscrviee inpcin of SG tubes repaired by A _

s_1eving a1 1 b performd at -c l i fr1e1uAnce.

1. Steam generator tube sleeves sall be speete1d Pi_

to initial operation and in service. The initial operating period before the initial inservice sample inspection shall not be shorter than six months nor I .

than months. The inspecitns of sleevesy shall be configured to ensure th.at each individual sleevc is inspected at least once In 60 monthsa.

2. if the results of the iseric iSnspction of SG tube sleeves eenduetId in accrdancei__ Tabe 5.5.2.11 2 fall in category C 3, 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 shall apply until the subsequent inspections satisfy the criteria for Category C 1.

f. Acceptance CritCria

1. Termns as used in this specification wvill be defined as a) Degradation A service Indeued cracking, wastage, wear, or general coroio ocurringj on either, inside or outside of-a tube, b) DBgradcd tube- A tube containing imperfections greater than or equal to 20°J of the nomi.nal wall thickness cause by degradation, C) 6 Degradation The percentage of the tube wall thickness affected or removed by degradation, d) Defect An imperfeetion of such severity that it exceeds the r lmit. A tube containing a defeet is defccottiud (conti nued)

SAN ONOFRE--UNIT 3 5.0-17 Amendment No. 116 132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.S.11 Steam Generator (SG) Tube Surveillance Program (eontinued) e) Imperfection An exception to the dimensions, finish, or contour of a tube from that required by fabrication drawings or specifications. [ddy current testing indications below 20 of the nominal tube wall thickness, if detectable, may be considered as imperfections; f) wh Repi tll Liitt1T4 Te merfection I I 1h1 depth UC, at or s beyond orL.

1o _ 1n 1~~~ - _ .s k_-

. ._i V.___. . I I Wil _

uupon detection of service induced servic degradation of the sleeve material or any portion of the sleeve to tube weld.

g) Preservice Inspection An inspection of the full leghof eac tueincchS performed by eddy

_urrnt AA _1 $A tehniques

._ _nii -AriP rr _ .!srvice te establish baslin Ucndii. of the tub~ing. This inspectionr shall be perfarmcd prior to initial MOD 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 ll ength f the ressure bounda" portion of the techniques prior to service. This includes pressure retaining portions of the parent tube in contact with t sleeve, sth leeve to tube we! d, and the pressure retaining port-ion of the sleeve.

h) Tub Isectin An inspection f the SG tube fromt the pointof entry (hot leg side) compltely arounld the U-bend to the top support of the cold leg excludi the ri ,,. ..- fhe tu e within the tubesheet (TS) below 5 inches from the secondary fac of th Te +

i) Unserviceable The condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in tha eveUn of Anl Oerational Basis Earthquake, a los ofcoant accent, or a steam line of fecdwa~ter line break accident as specified in Specification 5.5.2.11.e.

+ This exclusion is for Unit 3. Cyle 11 operation only.

(continued)

'SAN ONOFRE--UNIT 3 5.0-18 Amendment No. +BG

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SC) Tube Surveillance Program (continued) j)Tub Rh ar refers toaprcs that reestabliohes tube serv...i.,ablit. Accept.,able tube repairs will be performed by the following process; TIC welded sleeving as described in ACB/CE Topical Report, CEN 630 P,Rev. 2, is currently approved by 1-l 1;1\k .

T_ includes the installation by Velding If th. sleeves, heat tr'atment in aeordanee W...ith C 630-P, Rev. 2, to remove the stresses that are introduced by the sleeve installation, acceptance testing of the sleeve, and nondestructive examination for futr cp ison. Tube repair a be perfermed on certain tubes that have beent previeus!, lJuggd su u ao rreetivel Or pelventive the tube shall be p o a previ usly plugged tube prio to 1 eturning the tube to servi . _1

2. The SC shall be determined OPERABLE after completing J -gf__

_ 4_ is: _ _1% .. _I_ _ l 1 i.. _

VIU I C ll I VI UI I I Uii I U U through wall cracks, and plug all sleeved tubes that exceed the repair criteria) required by Tables

-5.5.2.11-1 and 5.5.2.11-2.

yg. Reports The content and frequency of written reports shall be in aecordance with T-echniceal-Specification5..2 "Special.

Reports."

(continued)

SAN ONOFRE--UNIT 3 5.0-19 Amendment No. 416-132

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5..11Steam r,pnpv ~ater Tube Surveillanee Program.

STEAM GENERATOR TUBE INSPECTION SUPLEMENTAL AP LING REQUIREMENTS (continued)

SAN ONOFRE--UNIT 3 5.0-19a Amendment No. 439,159

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued)

T.ll ' C rEln t t1 . I -F -II I LAU I %- J . .F . L- . L L - f- kvAv%- w a &I

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%4PAM &PnPPAtAV %lPPVPFI +*!hP 4nQnPP!t4An

_ v W M... I b_. _

s

,_ *lZ-r-- w ' "r 1st Sample inspeetion 2nd Sample Inspect~icn Sam! 541-e I Resultl jActien Required Resu-lt jAction-Requwfred NTAT Plug defeutiveg zcfe repird tuibes and ti Plug defetive, 19%° of the - repaired tubes--

£-4 sleeves in this.

%G Perform action C--4 for C 3 result inspeet a-H-repaied tubes NefIe Other SG is C 1 pi-gde ~f ee-6I e 2%of-e#the repair-ed-tutbes, sleeves. Perform action and i-nspeet- O%

of the sleeves Othr SG is C 2 fr C 2 result fIfirst_

sample.T s567 Is1 Tnpee- a+-

Netifieatiarn to inUbTT SU SU4 NRC pursuant to alnd Plug defeetive Othe Sc is r 3 repaired tubes.

Natification to NRC pursuant to 5.7.2 (continued)

SAN ONOFRE--UNIT 3 5.0-19b Amendment No. 132,159

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Cenerator (SC) Tube Surveillance Program (continued) 5.5.2.11.1 The inservice inspection may be limited to one SC on a rotating schedule encompassing 6%°of the tubes if the results of the first or previous inspections indicate that all SCs are performing in a like manner. Note that under some circumstances, the operating conditions in one SC may be found to be more severe than those in the other SC. Under such circumstances the sample sequence shall be modified to inspet the most severe conditions.

5.5.2.11.2 The other SG not inspected during the first isrieiseto shall be inspected. The third and subsequent inspectios1, shold follow the instructions described in Specification 5.5.2.11.1 above.