Text

Transmittal of TSTF-545, Revision 0, TS Inservice Testing (IST) Program Removal.
	ML13309A635
Person / Time
Site:	Technical Specifications Task Force
Issue date:	11/04/2013
From:	Croft W, Gustafson O, Loeffler R, Slough R; BWR Owners Group, PWR Owners Group, Technical Specifications Task Force
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	TSTF-13-09, TSTF-545, Rev 0
	Download: ML13309A635 (316)
	v • d • e

TECHNICAL SPECIFICATIONS TASK FORCE TSTF A JOINT OWNERS GROUP ACTIVITY November 4, 2013 TSTF-13-09 PROJ0753 Attn: Document Control Desk U. S. Nuclear Regulatory Commission Washington, DC 20555-0001

SUBJECT:

Transmittal of TSTF-545, Revision 0, "TS Inservice Testing (IST) Program Removal" Enclosed for NRC review is Revision 0 of TSTF-545, "TS Inservice Testing (IST) Program Removal." TSTF-545 is applicable to all plant types.

In a separate letter to the NRC's Chief Financial Officer, the TSTF has requested a fee waiver pursuant to the provisions of 10 CFR 170.11 for the review of TSTF-545.

Should you have any questions, please contact us.

Robert Slough (PWROG/W) Richard A. Loeffler (BWROG)

Otto W. Gustafson (PWROG/CE) Wendy E. Croft (PWROG/B&W)

Enclosure cc: Michelle Honcharik, Licensing Processes Branch, NRC Robert Elliott, Technical Specifications Branch, NRC 11921 Rockville Pike, Suite 100, Rockville, MD 20852 Phone: 301-984-4400, Fax: 301-984-7600 Administration by EXCEL Services Corporation

WOG-212, Rev. 0 TSTF-545, Rev. 0 Technical Specifications Task Force Improved Standard Technical Specifications Change Traveler TS Inservice Testing (IST) Program Removal NUREGs Affected: 1430 1431 1432 1433 1434 Classification: 1) Technical Change Recommended for CLIIP?: Yes Correction or Improvement: Correction NRC Fee Status: Exemption Requested Changes Marked on ISTS Rev 4.0 See attached.

Revision History OG Revision 0 Revision Status: Active Revision Proposed by: NRC Revision

Description:

Original Issue Owners Group Review Information Date Originated by OG: 31-May-13 Owners Group Comments (No Comments)

Owners Group Resolution: Approved Date: 25-Jun-13 TSTF Review Information TSTF Received Date: 27-Jun-13 Date Distributed for Review 27-Jun-13 OG Review Completed: BWOG WOG CEOG BWROG TSTF Comments:

On September 5, 2013, the TSTF provided a draft of TSTF-545 for NRC review. The TSTF had not created a Traveler with a request for an ASME Code alternative before and the NRC was asked to consider the approach. An internal NRC meeting was held on October 3 to discuss TSTF-545. The Component Branch has agreement from OGC to "fast track" a change to 10 CFR 50.55a to incorporate OMN-20 by January 2015. Therefore, the NRC recommended removing the Code Relief from the Traveler since it is unlikely that the NRC will approve TSTF-545 before then. However, after discussion, the recommendation is to remove the Code Relief from the Traveler but to keep it as an optional part of the model application in case a licensee wants to request the TS change before the CFR change is published.

The TSTF incorporated the NRC's recommended changes.

TSTF Resolution: Approved Date: 04-Nov-13 NRC Review Information NRC Received Date: 04-Nov-13 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 OG Revision 0 Revision Status: Active Affected Technical Specifications 1.1 Definitions Change

Description:

Added definition of INSERVICE TESTING PROGRAM SR 3.0.2 Bases SR Applicability LCO 3.0.6 LCO Applicability LCO 3.0.6 Bases LCO Applicability Bkgnd 3.8.6 Bases Battery Parameters LCO 3.8.6 Bases Battery Parameters Action 3.8.6.C Bases Battery Parameters SR 3.8.6.2 Bases Battery Parameters Action 3.8.9.A Bases Distribution Systems - Operating SR 3.4.10.1 Pressurizer Safety Valves NUREG(s)- 1430 1431 1432 Only SR 3.4.10.1 Bases Pressurizer Safety Valves NUREG(s)- 1430 1431 1432 Only SR 3.4.14.1 Bases RCS Pressure Isolation Valve (PIV) Leakage NUREG(s)- 1430 1431 1432 Only SR 3.5.2.4 ECCS - Operating NUREG(s)- 1430 1431 1432 Only SR 3.5.2.4 Bases ECCS - Operating NUREG(s)- 1430 1431 1432 Only SR 3.6.3.5 Containment Isolation Valves NUREG(s)- 1430 1431 1432 Only SR 3.6.3.5 Bases Containment Isolation Valves NUREG(s)- 1430 1431 1432 Only LCO 3.7.1 Bases MSSVs NUREG(s)- 1430 1431 1432 Only SR 3.7.1.1 MSSVs NUREG(s)- 1430 1431 1432 Only SR 3.7.1.1 Bases MSSVs NUREG(s)- 1430 1431 1432 Only SR 3.7.2.1 MSIVs NUREG(s)- 1430 1431 1432 Only SR 3.7.2.1 Bases MSIVs NUREG(s)- 1430 1431 1432 Only SR 3.7.3.1 MFSVs, MFCVs, and Associated SFCVs NUREG(s)- 1430 1431 1432 Only 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 SR 3.7.3.1 Bases MFSVs, MFCVs, and Associated SFCVs NUREG(s)- 1430 1431 1432 Only 5.5.8 Inservice Testing Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Deleted 5.5.9 Steam Generator (SG) Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.8 5.5.10 Secondary Water Chemistry Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.9 5.5.11 Ventilation Filter Testing Program (VFTP) NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.10 5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring NUREG(s)- 1430 1431 1432 Only Program Change

Description:

Renamed 5.5.11 5.5.13 Diesel Fuel Oil Testing Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.12 5.5.14 Technical Specifications (TS) Bases Control Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.13 and revision to Paragraph d 5.5.15 Safety Function Determination Program (SFDP) NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.14 5.5.16 Containment Leakage Rate Testing Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.15 5.5.17 Battery Monitoring and Maintenance Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.16 5.5.18 Control Room Envelope (CRE) Habitability Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.17 5.5.19 Setpoint Control Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.18 5.5.20 Surveillance Frequency Control Program NUREG(s)- 1430 1431 1432 Only Change

Description:

Renamed 5.5.19 Bkgnd 3.4.17 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1430 Only LCO 3.4.17 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1430 Only SR 3.4.17.1 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1430 Only SR 3.4.17.2 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1430 Only SR 3.5.2.5 Bases ECCS - Operating NUREG(s)- 1430 Only SR 3.6.6.4 Containment Spray and Cooling Systems NUREG(s)- 1430 Only 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 SR 3.6.6.4 Bases Containment Spray and Cooling Systems NUREG(s)- 1430 Only SR 3.7.5.2 EFW System NUREG(s)- 1430 Only SR 3.7.5.2 Bases EFW System NUREG(s)- 1430 Only SR 3.9.3.2 Bases Containment Penetrations NUREG(s)- 1430 Only SR 3.4.14.1 RCS Pressure Isolation Valve (PIV) Leakage NUREG(s)- 1431 1432 Only SR 3.6.12.1 Vacuum Relief Valves (Atmospheric and Ice Condenser) NUREG(s)- 1431 1432 Only SR 3.6.12.1 Bases Vacuum Relief Valves (Atmospheric and Ice Condenser) NUREG(s)- 1431 1432 Only SR 3.7.5.2 AFW System NUREG(s)- 1431 1432 Only SR 3.7.5.2 Bases AFW System NUREG(s)- 1431 1432 Only SR 3.4.12.4 LTOP System NUREG(s)- 1431 Only SR 3.4.12.4 Bases LTOP System NUREG(s)- 1431 Only SR 3.4.12.7 LTOP System NUREG(s)- 1431 Only SR 3.4.12.7 Bases LTOP System NUREG(s)- 1431 Only Bkgnd 3.4.20 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1431 Only LCO 3.4.20 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1431 Only SR 3.4.20 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1431 Only SR 3.4.20.2 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1431 Only SR 3.6.3.6 Bases Containment Isolation Valves NUREG(s)- 1431 Only SR 3.6.6C.2 Containment Spray System (Ice Condenser) NUREG(s)- 1431 Only SR 3.6.6D.2 QS System (Subatmospheric) NUREG(s)- 1431 Only SR 3.6.6C.2 Bases Containment Spray System (Ice Condenser) NUREG(s)- 1431 Only SR 3.6.6D.2 Bases QS System (Subatmospheric) NUREG(s)- 1431 Only SR 3.6.6B.4 Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1431 Only Dual)

SR 3.6.6A.4 Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1431 Only Dual)

SR 3.6.6B.4 Bases Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1431 Only Dual) 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 SR 3.6.6A.4 Bases Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1431 Only Dual)

SR 3.6.6E.5 RS System (Subatmospheric) NUREG(s)- 1431 Only SR 3.6.6E.5 Bases RS System (Subatmospheric) NUREG(s)- 1431 Only SR 3.6.9.1 Bases HMS (Atmospheric, Ice Condenser, and Dual) NUREG(s)- 1431 Only SR 3.9.4.2 Bases Containment Penetrations NUREG(s)- 1431 Only Bkgnd 3.4.18 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1432 Only LCO 3.4.18 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1432 Only SR 3.4.18.1 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1432 Only SR 3.4.18.2 Bases Steam Generator (SG) Tube Integrity NUREG(s)- 1432 Only SR 3.5.2.5 ECCS - Operating NUREG(s)- 1432 Only SR 3.5.2.5 Bases ECCS - Operating NUREG(s)- 1432 Only SR 3.5.2.8 Bases ECCS - Operating NUREG(s)- 1432 Only SR 3.6.6B.5 Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1432 Only Dual)

SR 3.6.6A.5 Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1432 Only Dual)

SR 3.6.6A.5 Bases Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1432 Only Dual)

SR 3.6.6B.5 Bases Containment Spray and Cooling Systems (Atmospheric and NUREG(s)- 1432 Only Dual)

SR 3.6.7.4 Spray Additive System (Atmospheric and Dual) NUREG(s)- 1432 Only SR 3.6.7.4 Bases Spray Additive System (Atmospheric and Dual) NUREG(s)- 1432 Only SR 3.1.7.7 SLC System NUREG(s)- 1433 1434 Only SR 3.1.7.7 Bases SLC System NUREG(s)- 1433 1434 Only SR 3.5.1.2 Bases ECCS - Operating NUREG(s)- 1433 1434 Only SR 3.5.2.5 ECCS - Shutdown NUREG(s)- 1433 1434 Only SR 3.5.2.5 Bases ECCS - Shutdown NUREG(s)- 1433 1434 Only SR 3.5.3.2 Bases RCIC System NUREG(s)- 1433 1434 Only SR 3.5.3.4 Bases RCIC System NUREG(s)- 1433 1434 Only 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 5.5.7 Inservice Testing Program NUREG(s)- 1433 1434 Only Change

Description:

Deleted 5.5.8 Ventilation Filter Testing Program (VFTP) NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.7 5.5.9 Explosive Gas and Storage Tank Radioactivity Monitoring NUREG(s)- 1433 1434 Only Program Change

Description:

Renumbered 5.5.8 5.5.10 Diesel Fuel Oil Testing Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.9 5.5.11 Technical Specifications (TS) Bases Control Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.10 5.5.12 Safety Function Determination Program (SFDP) NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.11 5.5.13 Primary Containment Leakage Rate Testing Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.12 5.5.14 Battery Monitoring and Maintenance Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.13 5.5.15 Control Room Envelope (CRE) Habitability Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.14 5.5.16 Setpoint Control Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.15 5.5.17 Surveillance Frequency Control Program NUREG(s)- 1433 1434 Only Change

Description:

Renumbered 5.5.16 SR 3.4.3.1 S/RVs NUREG(s)- 1433 Only SR 3.4.3.1 Bases S/RVs NUREG(s)- 1433 Only SR 3.4.5.1 RCS PIV Leakage NUREG(s)- 1433 Only SR 3.4.5.1 Bases RCS PIV Leakage NUREG(s)- 1433 Only SR 3.5.1.6 Bases ECCS - Operating NUREG(s)- 1433 Only SR 3.5.1.7 ECCS - Operating NUREG(s)- 1433 Only SR 3.5.1.7 Bases ECCS - Operating NUREG(s)- 1433 Only SR 3.6.1.3.6 PCIVs NUREG(s)- 1433 Only SR 3.6.1.3.6 Bases PCIVs NUREG(s)- 1433 Only SR 3.6.1.3.8 PCIVs NUREG(s)- 1433 Only 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 SR 3.6.1.3.8 Bases PCIVs NUREG(s)- 1433 Only SR 3.6.1.3.10 Bases PCIVs NUREG(s)- 1433 Only SR 3.6.1.7.2 Bases Reactor Building-to-Suppression Chamber Vacuum Breakers NUREG(s)- 1433 Only SR 3.6.1.8.2 Bases Suppression Chamber-to-Drywell Vacuum Breakers NUREG(s)- 1433 Only SR 3.6.2.3.2 RHR Suppression Pool Cooling NUREG(s)- 1433 Only SR 3.6.2.3.2 Bases RHR Suppression Pool Cooling NUREG(s)- 1433 Only SR 3.6.2.4.2 RHR Suppression Pool Spray NUREG(s)- 1433 Only SR 3.6.2.4.2 Bases RHR Suppression Pool Spray NUREG(s)- 1433 Only SR 3.6.3.1.1 Bases Drywell Cooling System Fans NUREG(s)- 1433 Only SR 3.6.4.2.2 SCIVs NUREG(s)- 1433 Only SR 3.6.4.2.2 Bases SCIVs NUREG(s)- 1433 Only SR 3.4.4.1 S/RVs NUREG(s)- 1434 Only SR 3.4.4.1 Bases S/RVs NUREG(s)- 1434 Only SR 3.4.6.1 RCS PIV Leakage NUREG(s)- 1434 Only SR 3.4.6.1 Bases RCS PIV Leakage NUREG(s)- 1434 Only SR 3.5.1.4 ECCS - Operating NUREG(s)- 1434 Only SR 3.5.1.4 Bases ECCS - Operating NUREG(s)- 1434 Only SR 3.6.1.3.5 PCIVs NUREG(s)- 1434 Only SR 3.6.1.3.5 Bases PCIVs NUREG(s)- 1434 Only SR 3.6.1.3.7 PCIVs NUREG(s)- 1434 Only SR 3.6.1.3.7 Bases PCIVs NUREG(s)- 1434 Only SR 3.6.1.7.2 RHR Containment Spray System NUREG(s)- 1434 Only SR 3.6.1.7.2 Bases RHR Containment Spray System NUREG(s)- 1434 Only SR 3.6.2.3.2 RHR Suppression Pool Cooling NUREG(s)- 1434 Only SR 3.6.2.3.2 Bases RHR Suppression Pool Cooling NUREG(s)- 1434 Only SR 3.6.3.2.1 Bases Drywell Purge System NUREG(s)- 1434 Only SR 3.6.4.2.2 SCIVs NUREG(s)- 1434 Only 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

WOG-212, Rev. 0 TSTF-545, Rev. 0 SR 3.6.4.2.2 Bases SCIVs NUREG(s)- 1434 Only SR 3.6.5.3.4 Drywell Isolation Valves NUREG(s)- 1434 Only SR 3.6.5.3.4 Bases Drywell Isolation Valves NUREG(s)- 1434 Only 04-Nov-13 Copyright(C) 2013, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

TSTF-545, Rev. 0

1.

SUMMARY

DESCRIPTION The Inservice Testing (IST) Program requirements, including the associated testing intervals, are provided in the American Society of Mechanical Engineers (ASME) Code for Operations and Maintenance of Nuclear Power Plants (OM Code), which licensees are required to follow by 10 CFR 50.55(f), "Inservice testing requirements."

The proposed change requests a revision to the Technical Specifications (TS) to eliminate the Chapter 5.0, "Administrative Controls," specification, "Inservice Testing Program," because the program is unnecessary following the availability of ASME Code Case OMN-20, "Inservice Test Frequency." A new defined term, "Inservice Testing Program," is added to TS Section 1.1, "Definitions." Existing uses of the term "Inservice Testing Program" in the TS and TS Bases are capitalized to indicate it is now a defined term. The SR 3.0.2 Bases are revised to clarify the application of Surveillance Requirement (SR) 3.0.2 to inservice tests.

A model application is included as Enclosure 1. The model may be used by licensees desiring to adopt this change following NRC approval. The proposed TS changes are included as .

2. DETAILED DESCRIPTION 2.1 Background Title 10 of the Code of Federal Regulations (10 CFR), Part 50, Section 50.55a, paragraph (b),

"Standards approved for incorporation by reference," references the approved standards required to be followed for systems and components of nuclear power reactors. 10 CFR 50.55a, paragraph (b)(3), references the ASME OM Code. 10 CFR 50.55a, paragraph (b)(6), "Operation and Maintenance of Nuclear Power Plants Code Cases," allows licensees to apply the ASME Code Cases listed in Regulatory Guide 1.192, "Operation and Maintenance Code Case Acceptability, ASME OM Code," without prior NRC approval subject to the conditions listed in 10 CFR 50.55a(b)(6), paragraphs (i) through (iii). 10 CFR 50.55a, paragraph (a)(3)(i) allows licensees to request the use of ASME Code Cases that are not referenced in the current version of Regulatory Guide 1.192.

The OM Code was developed and is maintained by the ASME OM Committee. The ASME publishes a new edition of the OM Code every three years and a new addendum every year. The latest editions and addenda of the OM Code that have been approved for use by the NRC are referenced in 10 CFR 50.55a(b). The ASME also publishes OM Code Cases yearly. Code Cases provide alternatives developed and approved by ASME or explain the intent of existing Code requirements.

The TS IST Program in Section 5.5, "Programs and Manuals," provides a table defining some of the IST frequencies and describes the relationship between the TS and the Inservice Testing requirements. The program states:

Page 1

TSTF-545, Rev. 0 5.5.X Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda terminology for inservice performing inservice testing testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities,

c. The provisions of SR 3.0.3 are applicable to inservice testing activities, and

d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

SR 3.0.2 states that an SR is considered met within its specified Frequency if the Surveillance is performed within 1.25 times the interval specified. SR 3.0.3 states that if a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater.

On August 23, 2012, the NRC issued Regulatory Issue Summary (RIS) 2012-10, "NRC Staff Position on Applying Surveillance Requirement 3.0.2 and 3.0.3 to Administrative Controls Program Tests." The RIS stated that the NRC staff had determined that restructuring TS chapters during the development of the Improved Standard Technical Specifications (ISTS) resulted in unintended consequences when Section 3.0, "Surveillance Requirement Applicability," provisions were made applicable to Section 5.0 TS. The NRC staff concluded that SR 3.0.2 and SR 3.0.3 cannot be applied to TS 5.5 for tests that are not associated with a TS SR.

Page 2

TSTF-545, Rev. 0 In order to provide time for licensees to address the NRC position, the NRC issued Enforcement Guidance Memorandum (EGM) 2012-001, "Dispositioning Noncompliance with Administrative Controls Technical Specifications Programmatic Requirements that Extend Test Frequencies and Allow Performance of Missed Tests," on February 24, 2012. The EGM states the NRC staff position that SR 3.0.2 and SR 3.0.3 cannot be applied to Inservice Tests. The staff evaluation of IST requirements under 10 CFR 50.55a determined that, if a licensee finds that the requirements of TS conflict with the requirements of 10 CFR 50.55a, then the licensee must amend their TS to comply with 10 CFR 50.55a. Also, with regard to the ASME OM Code and 10 CFR 50.55a, the OM Code did not make available test allowances similar to either SR 3.0.2 or SR 3.0.3 under 10 CFR 50.55a(f). Therefore, these allowances may not be applied to Inservice Tests. The EGM provided enforcement discretion to licensees to apply SR 3.0.2 to Inservice Tests and guidance on addressing missed Inservice Tests, pending revision to the ASME OM Code and the TS.

The EGM stated that the generic resolution of this issue will include a proposed Technical Specifications Task Force (TSTF) Traveler for revising the ISTS, and will include a model license amendment request, model Safety Evaluation, and model No Significant Hazards Consideration Determination. The TSTF Traveler will be made available using the NRC Consolidated Line Item Improvement Process (CLIIP) by issuance of a Notice of Availability (NOA) for the model, to allow timely processing of license amendments by the NRC. This Traveler was developed to facilitate generic resolution of this issue regarding the IST Program.

In January 2013, the ASME announced the availability of Code Case OMN-20, "Inservice Test Frequency." The Code Case states:

Inquiry: What alternative(s) may be applied to the test frequencies for pumps and valves specified in ASME OM Division: 1 Section IST 2009 Edition through OMa-2011 Addenda and all earlier editions and addenda of ASME OM Code?

Reply: It is the opinion of the [ASME OM] Committee that for the test frequencies for pumps and valves specified in ASME OM Division: 1 Section IST 2009 Edition through OMa-2011 Addenda and all earlier editions and addenda of ASME OM Code, the below requirements may be applied.

ASME OM Division: 1 Section IST and earlier editions and addenda of ASME OM Code specify component test frequencies based either on elapsed time periods (e.g.,

quarterly, 2 years, etc.) or based on the occurrence of plant conditions or events (e.g.,

cold shutdown, refueling outage, upon detection of a sample failure, following maintenance, etc.).

a) Components whose test frequencies are based on elapsed time periods shall be tested at the frequencies specified in Section IST with a specified time period between tests as shown in the table below. The specified time period between tests may be reduced or extended as follows:

1) For periods specified as less than 2 years, the period may be extended by up to 25% for any given test.

Page 3

TSTF-545, Rev. 0

2) For periods specified as greater than or equal to 2 years, the period may be extended by up to 6 months for any given test.

3) All periods specified may be reduced at the discretion of the owner (i.e.,

there is no minimum period requirement).

Period extension is to facilitate test scheduling and considers plant operating conditions that may not be suitable for performance of the required testing (e.g.,

performance of the test would cause an unacceptable increase in the plant risk profile due to transient conditions or other ongoing surveillance, test or maintenance activities). Period extensions are not intended to be used repeatedly merely as an operational convenience to extend test intervals beyond those specified.

Period extensions may also be applied to accelerated test frequencies (e.g.,

pumps in Alert Range) and other less than two year test frequencies not specified in the table below.

Period extensions may not be applied to the test frequency requirements specified in Subsection ISTD, Preservice and Inservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-water Reactor Nuclear Power Plants, as Subsection ISTD contains its own rules for period extensions.

Frequency Specified Time Period Between Tests Quarterly (or 92 days every 3 months)

Semiannually (or 184 days every 6 months)

Annually (or 366 days every year) x calendar years where x is a whole number x Years of years 2 b) Components whose test frequencies are based on the occurrence of plant conditions or events may not have their period between tests extended except as allowed by ASME OM Division: 1 Section IST 2009 Edition through OMa-2011 Addenda and earlier editions and addenda of ASME OM Code.

The Code Case differs from the current TS requirements in the following aspects:

The Code Case does not define the periods "Weekly," "Monthly," or "Every 9 months."

The Code Case allows tests required to be performed at periods greater than 2 years to be extended up to 6 months. The ISTS does not allow test periods greater than 2 years to be extended.

The Code Case does not address failure to perform an Inservice Test within its required period.

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TSTF-545, Rev. 0

The Code Case does not include the statement in the TS that the ASME OM Code may not supersede the requirements of any TS.

The NRC is currently pursing publication of OMN-20 in the regulations so that it may be used without plant-specific approval. Should the NRC approve this Traveler and a licensee desire to adopt the Traveler prior to NRC incorporation of OMN-20 into the regulations, the model application in Enclosure 1 contains an optional request for a plant-specific alternative to the ASME O&M code to utilize OMN-20.

The proposed change eliminates the TS Inservice Testing Program. The TS contain Surveillances that require testing or test intervals in accordance with the Inservice Testing Program. The elimination of the TS Inservice Testing Program from Section 5.5 of the TS could result in uncertainty regarding the correct application of these Surveillance Requirements.

Therefore, a new defined term, "Inservice Testing Program," is added to Section 1.1, "Definitions," in the Technical Specifications. It is defined as, "The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 10 CFR 50.55a(f)."

Following the Note in Section 1.1 of the TS, the existing uses of the term "Inservice Testing Program" are capitalized throughout the TS and TS Bases to indicate it is a defined term. The SR 3.0.2 Bases are revised to expand the existing discussion of frequencies specified in regulations to include inservice tests.

2.2 Proposed TS Change The proposed change eliminates the Inservice Testing Program from TS Section 5.5. Subsequent programs are renumbered to reflect elimination of the program and references to the renumbered programs are revised in the TS and TS Bases. It is anticipated that plant-specific requests to adopt this Traveler will mark the Section 5.5 program deleted and will not renumber the subsequent programs.

A new defined term, "Inservice Testing Program," is added to TS Section 1.1, "Definitions." It states, "The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 10 CFR 50.55a(f)."

The existing uses of the term "Inservice Testing Program" are capitalized throughout the TS and TS Bases to indicate it is a defined term. The phrase "Inservice Testing Program" may appear in different TS and TS Bases locations in plant-specific TS. Revising this phrase to be capitalized, wherever it may appear in a plant's TS and TS Bases, is within the scope of this proposed change.

The SR 3.0.2 Bases discussion of frequencies specified in the regulation is expanded to discuss inservice tests. Words in italics are added. Words that are struck-through are deleted.

"The 25% extension does not significantly degrade the reliability that results from performing the Surveillance at its specified Frequency. This is based on the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the SRs. The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The Page 5

TSTF-545, Rev. 0 requirements of regulations take precedence over the TS. An exampleExamples of where SR 3.0.2 does not apply are is in the [Primary] Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the American Society of Mechanical Engineers (ASME) Code inservice testing required by 10 CFR 50.55a.

These This programs establishes testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a test interval specified in the regulations directly or by reference."

3. TECHNICAL EVALUATION 3.2 Technical Evaluation of the Proposed Change to the Technical Specifications The proposed change eliminates TS Section 5.5, "Programs and Manuals," "Inservice Testing Program." This removes TS requirements related to IST frequencies, the application of SR 3.0.2 and SR 3.0.3, and the relationship between the TS and the ASME Code.

The existing references to the IST Program are revised to reference a new TS Section 1.1 defined term, "Inservice Testing Program," which states:

"The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 10 CFR 50.55a(f)."

Plant operation under the proposed alternative in OMN-20 and the proposed TS will differ from the current TS requirements in the following aspects:

The Code Case does not define the periods "Weekly," "Monthly," or "Every 9 months."

Unlike the existing TS IST Program, the OMN-20 Code Case does not define the periods "weekly," "monthly," or "every 9 months." As the ASME OM Committee specifies the pump and valve testing frequencies in the OM Code, we defer to that Committee regarding the need to define these testing periods in the Code Case or in the TS.

The Code Case allows tests required to be performed at periods greater than 2 years to be extended up to 6 months. The ISTS does not allow test periods greater than 2 years to be extended.

The ASME OM Committee determined that allowing a 6-month extension to testing periods greater than 2 years is appropriate. The 6-month extension will have minimal impact on component reliability considering that the most probable result of performing any inservice test is satisfactory verification of the test acceptance criteria. As such, pumps and valves will continue to be adequately assessed for operational readiness when tested in accordance with the requirements specified in 10 CFR 50.55a(f) with the frequency extensions allowed by Code Case OMN-20.

The Code Case does not address failure to perform an Inservice Test within its required period.

The current TS allow SR 3.0.3 to be used when an Inservice Test is not performed within its required testing period. SR 3.0.3 states that if a Surveillance was not performed within its Page 6

TSTF-545, Rev. 0 specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. RIS 2012-10 stated licensees cannot use TS 5.5.6 to apply SR 3.0.3 to an inservice test under 10 CFR 50.55a(f) that is not associated with a TS surveillance.

In EGM 2012-001, the NRC stated that failure to either perform or meet an inservice test for tests required only by 10 CFR 50.55a(f) results in a nonconformance with the OM Code requirements and should be resolved as discussed in RIS 2005-20, Revision 1. RIS 2005-20, Revision 1, announced the availability of NRC Inspection Manual Part 9900, Technical Guidance, "Operability Determinations & Functionality Assessments for Resolution of Degraded and Nonconforming Conditions Adverse to Quality or Safety" (herein referred to as the "OD Process"). In other words, if it is discovered that an inservice test was not performed within the specified period, the effect on equipment Operability must be assessed.

The guidance in EGM 2012-001 is consistent with Section 6.2 of the OD Process, which states, "In some cases a licensee may discover a noncompliance with a regulation. The noncompliance with the regulation should be treated as a degraded or nonconforming condition, and the operability or functionality of affected SSCs assessed." Therefore, following adoption of the proposed Code Case and the proposed change to the TS, failure to perform an inservice test within the period specified in the OM Code as modified by Code Case OMN-20 will be treated as a degraded or nonconforming condition and the effect on the Operability of the affected components will be assessed. Should it be determined that the affected components are inoperable, the appropriate TS Actions will be taken.

The proposed change to delete the SR 3.0.3 allowance is considered more restrictive since the OM Code, applicable addenda, and Regulatory Guide 1.192 incorporated by reference in 10 CFR 50.55a(b) do not provide an equivalent allowance to generically delay performance of an inservice test due to discovery of a missed test. Although SR 3.0.3 will continue to apply to TS LCOs and associated surveillance requirements that reference the IST Program, the SR 3.0.3 allowance will not apply to non-TS inservice testing requirements.

The Code Case does not include the statement in the TS that the ASME OM Code may not supersede the requirements of any TS.

The current TS IST Program, Paragraph d, states, "Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS." This statement has been in the ISTS since Revision 0 was issued in 1992, and in the pre-ISTS equivalent requirement (4.0.5) since 1978, or earlier.

EGM 2012-001 stated, "the staff evaluation of inservice testing requirements under 10 CFR 50.55a determined that, if a licensee finds that the requirements of TS conflict with the requirements of 10 CFR 50.55a, then the licensee must amend their TS to comply with 10 CFR 50.55a." As the NRC position is that the statement in Paragraph d is incorrect, it is removed in the proposed change.

Page 7

TSTF-545, Rev. 0 SR 3.0.2 will no longer apply to frequencies specified in the Inservice Testing Program Inservice testing frequencies are specified in the ASME OM Code, as modified by OMN-20, and 10 CFR 50.55a(f) requires licensees to implement the ASME OM Code. The Technical Specifications cannot supersede regulations and, therefore, SR 3.0.2 may not be used to extend the testing frequencies specified in the ASME OM Code. The existing SR 3.0.2 Bases discussion regarding the inability of SR 3.0.2 to alter frequencies specified in regulations is expanded to discuss inservice testing. OMN-20 adds this test scheduling flexibility to the ASME OM Code, so it is not needed in the TS.

Plant operation under the proposed alternative (OMN-20) and the proposed changes to the TS will have no significant effect on component reliability.

4. REGULATORY EVALUATION OF THE PROPOSED TS CHANGE 4.1 Applicable Regulatory Requirements/Criteria 10 CFR 50.55a(b), "Standards approved for incorporation by reference," references the approved standards required to be followed for systems and components of nuclear power reactors.

10 CFR 50.55a, paragraph (b)(3), references the ASME OM Code. 10 CFR 50.55a, paragraph (b)(6), "Operation and Maintenance of Nuclear Power Plants Code Cases," allows licensees to apply the ASME Code Cases listed in Regulatory Guide 1.192, "Operation and Maintenance Code Case Acceptability, ASME OM Code," without prior NRC approval subject to the conditions listed in 10 CFR 50.55a(b)(6), paragraphs (i) through (iii). 10 CFR 50.55a, paragraph (a)(3)(i) allows licensees to request the use of ASME Code Cases that are not referenced in the current version of Regulatory Guide 1.192. The use of the approved ASME OM Code Case OMN-20 is consistent with these regulations.

10 CFR 50.36(c)(5), "Administrative controls," states, "Administrative controls are the provisions relating to organization and management, procedures, recordkeeping, review and audit, and reporting necessary to assure operation of the facility in a safe manner. Each licensee shall submit any reports to the Commission pursuant to approved technical specifications as specified in § 50.4." The proposed change to the TS Inservice Testing Program does not affect compliance with this requirement.

Therefore, the proposed change to the TS does not affect plant compliance with these regulations.

4.2 No Significant Hazards Consideration Determination The Technical Specification Task Force (TSTF) has evaluated the proposed change to the Technical Specifications (TS) Administrative Controls Section, Inservice Testing (IST) Program against the criteria of 10 CFR 50.92(c) to determine if any significant hazards consideration is involved. The TSTF has concluded that the proposed change does not involve a significant hazards consideration. The following is a discussion of how each of the 10 CFR 50.92(c) criteria is satisfied.

Page 8

TSTF-545, Rev. 0

1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed change revises Chapter 5, "Administrative Controls," Section 5.5, "Programs and Manuals," by eliminating the "Inservice Testing Program" specification.

Requirements in the IST Program are removed, as they are duplicative of requirements in the American Society of Mechanical Engineers (ASME) Operations and Maintenance (OM) Code, as clarified by Code Case OMN-20, "Inservice Test Frequency." Other requirements in the Section 5.5 IST Program are eliminated because the Nuclear Regulatory Commission (NRC) has determined their inclusion in the TS is contrary to regulations. A new defined term, "Inservice Testing Program," is added which references the requirements of 10 CFR 50.55a(f).

Performance of inservice testing is not an initiator to any accident previously evaluated.

As a result, the probability of occurrence of an accident is not significantly affected by the proposed change. Inservice test periods under Code Case OMN-20 are equivalent to the current testing period allowed by the TS with the exception that testing periods greater than 2 years may be extended by up to 6 months to facilitate test scheduling and consideration of plant operating conditions that may not be suitable for performance of the required testing. The testing period extension will not affect the ability of the components to mitigate any accident previously evaluated as the components are required to be operable during the testing period extension. Performance of inservice tests utilizing the allowances in OMN-20 will not significantly affect the reliability of the tested components. As a result, the availability of the affected components, as well as their ability to mitigate the consequences of accidents previously evaluated, is not affected.

Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed change create the possibility of a new or different kind of accident from any previously evaluated?

Response: No The proposed change does not alter the design or configuration of the plant. The proposed change does not involve a physical alteration of the plant; no new or different kind of equipment will be installed. The proposed change does not alter the types of inservice testing performed. In most cases, the frequency of inservice testing is unchanged. However, the frequency of testing would not result in a new or different kind of accident from any previously evaluated since the testing methods are not altered.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated.

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TSTF-545, Rev. 0

3. Does the proposed change involve a significant reduction in a margin of safety?

Response: No The proposed change eliminates some requirements from the TS in lieu of requirements in the ASME Code, as modified by use of Code Case OMN-20. Compliance with the ASME Code is required by 10 CFR 50.55a. The proposed change also allows inservice tests with periods greater than 2 years to be extended by 6 months to facilitate test scheduling and consideration of plant operating conditions that may not be suitable for performance of the required testing. The testing period extension will not affect the ability of the components to respond to an accident as the components are required to be operable during the testing period extension. The proposed change will eliminate the existing TS SR 3.0.3 allowance to defer performance of missed inservice tests up to the duration of the specified testing period, and instead will require an assessment of the missed test on equipment operability. This assessment will consider the effect on a margin of safety (equipment operability). Should the component be inoperable, the Technical Specifications provide actions to ensure that the margin of safety is protected.

The proposed change also eliminates a statement that nothing in the ASME Code should be construed to supersede the requirements of any TS. The NRC has determined that statement to be incorrect. However, elimination of the statement will have no effect on plant operation or safety.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

4.3 Conclusions In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commissions regulations, and (3) approval of the proposed change will not be inimical to the common defense and security or to the health and safety of the public.

5. ENVIRONMENTAL CONSIDERATION OF THE PROPOSED TS CHANGE A review has determined that the proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or a significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

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TSTF-545, Rev. 0

6. REFERENCES

1. Regulatory Issue Summary 2012-10, "NRC Staff Position on Applying Surveillance Requirement 3.0.2 and 3.0.3 to Administrative Controls Program Tests," dated August 23, 2012.

2. Enforcement Guidance Memorandum 2012-001, "Dispositioning Noncompliance with Administrative Controls Technical Specifications Programmatic Requirements that Extend Test Frequencies and Allow Performance of Missed Tests," dated February 24, 2012.

3. American Society of Mechanical Engineers Code Case OMN-20, "Inservice Test Frequency," issued January 2013.

4. NRC Inspection Manual Part 9900, Technical Guidance, "Operability Determinations &

Functionality Assessments for Resolution of Degraded and Nonconforming Conditions Adverse to Quality or Safety," Revision 1, dated April 16, 2008 (ADAMS Accession Number ML073440103)."

5. Regulatory Guide 1.192, "Operation and Maintenance Code Case Acceptability, ASME OM Code," June 2003.

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TSTF-545, Rev. 0 Enclosure 1 Model Application

NOTE: Discussion of adopting an alternative to the ASME Code is in braces ({}). If OMN-20 has been previously adopted by a licensee, or if OMN-20 has been incorporated into the regulations such that a request for alternative is not required, the information in TSTF-545, Rev. 0 braces should be removed.

[DATE] 10 CFR 50.90

{10 CFR 50.55a}

ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001 DOCKET NO. PLANT NAME 50-[xxx]

SUBJECT:

Application To Revise Technical Specifications to Adopt TSTF-545, Revision 0, "10 CFR 50.55a(f) Alternative IST Testing Request and IST Program Revision," {and to Request an Alternative to the ASME Code}

Pursuant to 10 CFR 50.90, [LICENSEE] is submitting a request for an amendment to the Technical Specifications (TS) for [PLANT NAME, UNIT NOS.].

The proposed change revises the Technical Specifications (TS) to eliminate the Section 5.5, "Inservice Test Program," which is superseded by OMN-20. A new defined term, "Inservice Testing Program," is added to the TS. This request is consistent with TSTF-545, Revision 0, "10 CFR 50.55a(f) Alternative IST Testing Request and IST Program Revision." {The proposed change also proposes an alternative to the testing periods in the American Society of Mechanical Engineers (ASME) Operation and Maintenance (OM) Code, by adoption of approved Code Case OMN-20, "Inservice Test Frequency."} provides a description and assessment of the proposed TS changes. {Attachment 2 provides the request for an alternative to the ASME Code.} Attachment [3] provides the existing TS pages marked up to show the proposed changes. Attachment [4] provides revised (clean) TS pages.

Approval of the proposed amendment is requested by [date]. Once approved, the amendment shall be implemented within [xx] days.

In accordance with 10 CFR 50.91, a copy of this application, with attachments, is being provided to the designated [STATE] Official.

[In accordance with 10 CFR 50.30(b), a license amendment request must be executed in a signed original under oath or affirmation. This can be accomplished by attaching a notarized affidavit confirming the signature authority of the signatory, or by including the following statement in the cover letter: "I declare under penalty of perjury that the foregoing is true and correct.

Executed on (date)." The alternative statement is pursuant to 28 USC 1746 and does not require notarization.]

TSTF-545, Rev. 0 If you should have any questions regarding this submittal, please contact [NAME, TELEPHONE NUMBER].

Sincerely,

[Name, Title]

Attachments: 1. Description and Assessment of Technical Specifications Changes

{2. Description and Assessment of the Proposed Alternative to the ASME Code}

[3]. Proposed Technical Specification Changes (Mark-Up)

[4]. Revised Technical Specification Pages Note: Attachments [3] and [4] are not included in the model application.

cc: NRC Project Manager NRC Regional Office NRC Resident Inspector State Contact

TSTF-545, Rev. 0 ATTACHMENT 1 DESCRIPTION AND ASSESSMENT OF TECHNICAL SPECIFICATIONS CHANGES

1.0 DESCRIPTION

The proposed change eliminates the Technical Specifications (TS), Section 5.5, "Inservice Test (IST) Program," to eliminate requirements duplicated in American Society of Mechanical Engineers (ASME) Code for Operations and Maintenance of Nuclear Power Plants (OM Code),

Case OMN-20, "Inservice Test Frequency." A new defined term, "Inservice Testing Program,"

is added to TS Section 1.1, "Definitions." The proposed change to the TS is consistent with TSTF 545, Revision 0, "10 CFR 50.55a(f) Alternative IST Testing Request and IST Program Revision."

2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation

[LICENSEE] reviewed the model safety evaluation dated [DATE] as part of the Federal Register Notice of Availability. This review included a review of the NRC staffs evaluation, as well as the information provided in TSTF-545, Revision 0. [LICENSEE] concluded that the justifications presented in TSTF-545, Revision 0, and the model safety evaluation prepared by the NRC staff are applicable to [PLANT, UNIT NOS.] and justify this amendment for the incorporation of the changes to the [PLANT] TS.

2.2 Optional Changes and Variations

[LICENSEE is not proposing any variations or deviations from the TS changes described in the TSTF-545, Revision 0, or the applicable parts of the NRC staffs model safety evaluation dated

[DATE].] [LICENSEE is proposing the following variations from the TS changes described in the TSTF-545, Revision 0, or the applicable parts of the NRC staffs model safety evaluation dated [DATE].]

[The [PLANT] TS utilize different [numbering][and][titles] than the Standard Technical Specifications on which TSTF-545, Revision 0, was based. Specifically, [describe differences between the plant-specific TS numbering and/or titles and the TSTF-545, Revision 0, numbering and titles.] These differences are administrative and do not affect the applicability of TSTF-545, Revision 0, to the [PLANT] TS.]

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Determination

[LICENSEE] requests adoption of the Technical Specification (TS) changes described in TSTF-545, Revision 0, "10 CFR 50.55a(f) Alternative IST Testing Request and IST Program Revision," which is an approved change to the Improved Standard Technical Specifications (ISTS), into the [PLANT NAME, UNIT NOS] Technical Specifications (TS). The proposed

TSTF-545, Rev. 0 change revises the TS Chapter 5, "Administrative Controls," Section 5.5, "Programs and Manuals," to delete the "Inservice Testing (IST) Program" specification. Requirements in the IST Program are removed, as they are duplicative of requirements in the ASME OM Code, as clarified by Code Case OMN-20, "Inservice Test Frequency." Other requirements in Section 5.5 are eliminated because the Nuclear Regulatory Commission (NRC) has determined their appearance in the TS is contrary to regulations. A new defined term, "Inservice Testing Program," is added, which references the requirements of 10 CFR 50.55a(f). LICENSEE] has evaluated whether or not a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:

1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed change revises Chapter 5, "Administrative Controls," Section 5.5, "Programs and Manuals," by eliminating the "Inservice Testing Program" specification.

Requirements in the IST Program are removed, as they are duplicative of requirements in the American Society of Mechanical Engineers (ASME) Operations and Maintenance (OM) Code, as clarified by Code Case OMN-20, "Inservice Test Frequency." Other requirements in the Section 5.5 IST Program are eliminated because the Nuclear Regulatory Commission (NRC) has determined their inclusion in the TS is contrary to regulations. A new defined term, "Inservice Testing Program," is added which references the requirements of 10 CFR 50.55a(f).

Performance of inservice testing is not an initiator to any accident previously evaluated.

As a result, the probability of occurrence of an accident is not significantly affected by the proposed change. Inservice test periods under Code Case OMN-20 are equivalent to the current testing period allowed by the TS with the exception that testing periods greater than 2 years may be extended by up to 6 months to facilitate test scheduling and consideration of plant operating conditions that may not be suitable for performance of the required testing. The testing period extension will not affect the ability of the components to mitigate any accident previously evaluated as the components are required to be operable during the testing period extension. Performance of inservice tests utilizing the allowances in OMN-20 will not significantly affect the reliability of the tested components. As a result, the availability of the affected components, as well as their ability to mitigate the consequences of accidents previously evaluated, is not affected.

Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed change create the possibility of a new or different kind of accident from any previously evaluated?

Response: No

TSTF-545, Rev. 0 The proposed change does not alter the design or configuration of the plant. The proposed change does not involve a physical alteration of the plant; no new or different kind of equipment will be installed. The proposed change does not alter the types of inservice testing performed. In most cases, the frequency of inservice testing is unchanged. However, the frequency of testing would not result in a new or different kind of accident from any previously evaluated since the testing methods are not altered.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated.

3. Does the proposed change involve a significant reduction in a margin of safety?

Response: No The proposed change eliminates some requirements from the TS in lieu of requirements in the ASME Code, as modified by use of Code Case OMN-20. Compliance with the ASME Code is required by 10 CFR 50.55a. The proposed change also allows inservice tests with periods greater than 2 years to be extended by 6 months to facilitate test scheduling and consideration of plant operating conditions that may not be suitable for performance of the required testing. The testing period extension will not affect the ability of the components to respond to an accident as the components are required to be operable during the testing period extension. The proposed change will eliminate the existing TS SR 3.0.3 allowance to defer performance of missed inservice tests up to the duration of the specified testing period, and instead will require an assessment of the missed test on equipment operability. This assessment will consider the effect on a margin of safety (equipment operability). Should the component be inoperable, the Technical Specifications provide actions to ensure that the margin of safety is protected.

The proposed change also eliminates a statement that nothing in the ASME Code should be construed to supersede the requirements of any TS. The NRC has determined that statement to be incorrect. However, elimination of the statement will have no effect on plant operation or safety.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

Based on the above, [LICENSEE] concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified.

4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change

TSTF-545, Rev. 0 meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

NOTE: This attachment is not required if OMN-20 has been previously adopted by a licensee, or if OMN-20 has been incorporated into the regulations such that a request for TSTF-545, Rev. 0 alternative is not required.

{ ATTACHMENT 2 DESCRIPTION AND ASSESSMENT OF THE PROPOSED ALTERNATIVE TO THE ASME CODE Request in Accordance with 10 CFR 50.55a(a)(3)(i)

Alternative Provides Acceptable Level of Quality and Safety

1.0 DESCRIPTION

The request is to adopt a proposed alternative to the American Society of Mechanical Engineers (ASME) Operation and Maintenance (OM) Code by adoption of approved Code Case OMN-20, "Inservice Test Frequency."

2.0 ASSESSMENT 3.1 Technical Evaluation of the Proposed Alternative to the OM Code Section IST of Division 1 of the OM Code, which is incorporated by reference in 10 CFR 50.55a(b)(3), specifies component test frequencies based either on elapsed time periods (e.g., quarterly, 2 years) or on the occurrence of a plant condition or event (e.g., cold shutdown, refueling outage).

The IST Program controls specified in Section 5.5 of TS provide: a) a table specifying certain IST frequencies; b) an allowance to apply SR 3.0.2 to inservice tests required by the OM Code and with frequencies of two years or less; c) an allowance to apply SR 3.0.3 to inservice tests required by the OM Code; and d) a statement that, "Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS." In Regulatory Issue Summary (RIS) 2012-10, "NRC Staff Position on Applying Surveillance Requirement 3.0.2 and 3.0.3 to Administrative Controls Program Tests," and Enforcement Guidance Memorandum (EGM) 2012-001, "Dispositioning Noncompliance with Administrative Controls Technical Specifications Programmatic Requirements that Extend Test Frequencies and Allow Performance of Missed Tests," the NRC stated that items b, c, and d of the TS IST Program were inappropriately added to the TS and may not be applied (although the EGM allows licensees to continue to apply those paragraphs pending a generic resolution of the issue).

ASME Code Case OMN-20, "Inservice Test Frequency," has been approved for use by the ASME OM committee as an alternative to the test frequencies for pumps and valves specified in ASME OM Division: 1 Section IST 2009 Edition through OMa-2011 Addenda, and all earlier editions and addenda of ASME OM Code.

Code Case OMN-20 is not referenced in the latest revision of Regulatory Guide 1.192 (June 2003) as an acceptable OM Code Case to comply with 10 CFR 50.55a(f) requirements as allowed by 10 CFR 50.55a(b)(6). The proposed alternative is to permanently use Code Case

TSTF-545, Rev. 0 OMN-20 to extend or reduce the IST frequency requirements until OMN-20 is incorporated into the next revision of Regulatory Guide 1.192.

ASME Code Components Affected The Code Case applies to pumps and valves specified in ASME OM Division: 1 Section IST 2009 Edition through OMa-2011 Addenda and all earlier editions and addenda of ASME OM Code. Period extensions may also be applied to accelerated test frequencies (e.g., pumps in Alert Range) as specified in OMN-20.

For pumps and valves with test periods of 2 years of less, the test period allowed by OMN-20 and the current TS Inservice Testing Program (as modified by SR 3.0.2 and EGM 2012-001) are the same. For pumps and valves with test periods greater than 2 years, OMN-20 allows the test period to be extended by 6 months. The current TS Inservice Testing Program does not allow extension of test periods that are greater than 2 years.

Applicable Code Edition and Addenda

ASME Code Case OMN-20 applies to ASME OM Division: 1 Section IST 2009 Edition through OMa-2011Addenda and all earlier editions and addenda of ASME OM Code.

The [PLANT] Code Edition and Addenda that are applicable to the program interval are

[Provide the plant-specific Code Edition and Addenda that are applicable to the program interval for the request.] The [PLANT] current interval ends [DATE].

Applicable Code Requirement

This request is made in accordance with 10 CFR 50.55a(a)(3), and proposes an alternative to the requirements of 10 CFR 50.55a(f), which requires pumps and valves to meet the test requirements set forth in specific documents incorporated by reference in 10 CFR 50.55a(b).

ASME Code Case OMN-20 applies to Division 1, Section IST of the ASME OM Code and associated addenda, which are incorporated by reference in 10 CFR 50.55a(b)(3).

Reason for Request

In RIS 2012-10 and EGM 2012-001, the NRC stated that the current TS allowance to apply SR 3.0.2 and SR 3.0.3 to the Inservice Testing Program would no longer be permitted. In response, OMN-20, which provides allowances similar to SR 3.0.2, was approved and is proposed to be used as an alternative to the test periods specified in the OM code. The proposed change substitutes an approved Code Case for existing TS requirements that the NRC has determined are legally, but not technically, unacceptable as a TS allowance.

Proposed Alternative and Basis for Use The proposed alternative is OMN-20, "Inservice Test Frequency," which addresses testing periods for pumps and valves specified in ASME OM Division 1, Section IST, 2009 Edition through OMa-2011 Addenda, and all earlier editions and addenda of ASME OM Code.

TSTF-545, Rev. 0 This request is being made in accordance with 10 CFR 50.55a(a)(3)(i) and is considered an alternative that provides an acceptable level of quality and safety for the following reasons:

1) For IST testing periods up to and including 2 years, Code Case OMN-20 provides an allowance to extend the IST testing periods by up to 25%. The period extension is to facilitate test scheduling and considers plant operating conditions that may not be suitable for performance of the required testing (e.g., performance of the test would cause an unacceptable increase in the plant risk profile due to transient conditions or other ongoing surveillance, test or maintenance activities). Period extensions are not intended to be used repeatedly merely as an operational convenience to extend test intervals beyond those specified. The test period extension and the statements regarding the appropriate use of the period extension are equivalent to the existing TS SR 3.0.2 allowance and the statements regarding its use in the SR 3.0.2 Bases. Use of the SR 3.0.2 period extension has been a practice in the nuclear industry for many decades and there is no evidence that the period extensions affect component reliability.

2) For IST testing periods of greater than 2 years, OMN-20 allows an extension of up to 6 months. The ASME OM Committee determined that such an extension is appropriate. The 6-month extension will have a minimal impact on component reliability considering that the most probable result of performing any inservice test is satisfactory verification of the test acceptance criteria. As such, pumps and valves will continue to be adequately assessed for operational readiness when tested in accordance with the requirements specified in 10 CFR 50.55a(f) with the frequency extensions allowed by Code Case OMN-20.

3) As stated in EGM 2012-001, if an Inservice Test is not performed within its frequency, SR 3.0.3 will not be applied. The effect of a missed Inservice Test on the Operability of TS equipment will be assessed under the licensee's Operability Determination Program.

Duration of Proposed Alternative The proposed alternative is requested to be permanent, effective through the term of the current

[renewed] license, or until Code Case OMN-20 is incorporated into a future revision of Regulatory Guide 1.192, whichever occurs first.

Precedents The NRC approved the use of OMN-20 for Quad Cities on February 14, 2013 (NRC ADAMS Accession Number ML13042A348). }

TSTF-545, Rev. 0 Enclosure 2 Traveler Technical Specification Markup

TSTF-545, Rev. 0 Definitions 1.1 1.1 Definitions EMERGENCY FEEDWATER The EFIC RESPONSE TIME shall be that time interval from INITIATION AND CONTROL when the monitored parameter exceeds its EFIC actuation (EFIC) RESPONSE TIME setpoint at the channel sensor until the emergency feedwater equipment is capable of performing its function (i.e., valves travel to their required positions, pumps discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time interval from FEATURE (ESF) RESPONSE when the monitored parameter exceeds its ESF actuation TIME setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except RCP seal water injection or 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 to the Secondary System (primary to secondary LEAKAGE),

b. Unidentified LEAKAGE Babcock & Wilcox STS 1.1-3 Rev. 4.0

TSTF-545, Rev. 0 LCO Applicability 3.0 3.0 LCO Applicability LCO 3.0.4 (continued)

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with Specification 5.5.1415, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

LCO 3.0.7 Test Exception LCOs [3.1.9, 3.1.10, 3.1.11, and 3.4.19] allow specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Test Exception LCOs is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met.

When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

Babcock & Wilcox STS 3.0-2 Rev. 4.0

TSTF-545, Rev. 0 Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE In accordance in accordance with the Inservice Testing Program with the INSERVICE TESTING PROGRAM. Following INSERVICE testing, lift settings shall be within +/- 1%. TESTING PROGRAM Inservice Testing Program Babcock & Wilcox STS 3.4.10-2 Rev. 4.0

TSTF-545, Rev. 0 RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 ------------------------------NOTES-----------------------------

1. Not required to be performed in MODES 3 and 4.

2. Not required to be performed on the RCS PIVs located in the DHR flow path when in the DHR mode of operation.

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to [ In accordance 0.5 gpm per nominal inch of valve size up to a with the maximum of 5 gpm at an RCS pressure INSERVICE

[2215] psia and [2255] psia. TESTING PROGRAM Inservice Testing Program OR

[ [18] months]

OR In accordance with the Surveillance Frequency Control Program ]

AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months Babcock & Wilcox STS 3.4.14-3 Rev. 4.0

TSTF-545, Rev. 0 ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 [ Verify the following valves are in the listed position [ 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power to the valve operator removed.

OR Valve Number Position Function

[ ] [ ] [ ] In accordance

[ ] [ ] [ ] with the

[ ] [ ] [ ] Surveillance Frequency Control Program ] ]

SR 3.5.2.2 Verify each ECCS manual, power operated, and [ 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the OR correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.5.2.3 [ Verify ECCS piping is full of water. [ 31 days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.5.2.4 Verify each ECCS pump's developed head at the In accordance test flow point is greater than or equal to the with the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program Babcock & Wilcox STS 3.5.2-2 Rev. 4.0

TSTF-545, Rev. 0 Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.3 -------------------------------NOTE------------------------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual valve and [ 31 days blind flange that is located outside containment and not locked, sealed, or otherwise secured and is OR required to be closed during accident conditions is closed, except for containment isolation valves that In accordance are open under administrative controls. with the Surveillance Frequency Control Program ]

SR 3.6.3.4 -------------------------------NOTE------------------------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment and MODE 4 from not locked, sealed, or otherwise secured and MODE 5 if not required to be closed during accident conditions is performed within closed, except for containment isolation valves that the previous are open under administrative controls. 92 days SR 3.6.3.5 Verify the isolation time of each automatic power [In accordance operated containment isolation valve is within limits. with the INSERVICE TESTING PROGRAM Inservice Testing Program OR

[92 days]

OR In accordance with the Surveillance Babcock & Wilcox STS 3.6.3-8 Rev. 4.0

TSTF-545, Rev. 0 Containment Isolation Valves 3.6.3 Frequency Control Program ]

Babcock & Wilcox STS 3.6.3-9 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.2 Operate each [required] containment cooling train [ 31 days fan unit for 15 minutes.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6.3 Verify each [required] containment cooling train [ 31 days cooling water flow rate is [1780] gpm.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6.4 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with the the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in [ [18] months the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position OR on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program ]

Babcock & Wilcox STS 3.6.6-3 Rev. 4.0

TSTF-545, Rev. 0 MSSVs 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify each required MSSV lift setpoint per In accordance Table 3.7.1-1 in accordance with the INSERVICE with the TESTING PROGRAM Inservice Testing Program. INSERVICE Following testing, lift settings shall be within +/- 1%. TESTING PROGRAM Inservice Testing Program Babcock & Wilcox STS 3.7.1-2 Rev. 4.0

TSTF-545, Rev. 0 MSIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify isolation time of each MSIV is within limits. In accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.7.2.2 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify each MSIV actuates to the isolation position [ [18] months on an actual or simulated actuation signal.

OR In accordance with the Surveillance Frequency Control Program ]

Babcock & Wilcox STS 3.7.2-2 Rev. 4.0

TSTF-545, Rev. 0

[MFSVs, MFCVs, and Associated SFCVs]

3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two valves in the same D.1 Isolate affected flow path. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flow path inoperable for one or more flow paths.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. [ AND E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ]

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify the isolation time of each [MFSV], [MFCV], In accordance and [SFCV] is within limits. with the INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.7.3.2 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify each [MFSV], [MFCV], and [SFCV] actuates [ [18] months to the isolation position on an actual or simulated actuation signal. OR In accordance with the Surveillance Frequency Control Program ]

Babcock & Wilcox STS 3.7.3-2 Rev. 4.0

TSTF-545, Rev. 0 EFW System 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required EFW train F.1 Initiate action to restore Immediately inoperable in MODE 4. EFW train to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each EFW manual, power operated, and [ 31 days automatic valve in each water flow path and in both steam supply flow paths to the steam turbine driven OR pumps, that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance Frequency Control Program ]

SR 3.7.5.2 -------------------------------NOTE------------------------------

Not required to be performed for the turbine driven EFW pumps, until [24] hours after reaching

[800] psig in the steam generators.

Verify the developed head of each EFW pump at the In accordance flow test point is greater than or equal to the with the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program Babcock & Wilcox STS 3.7.5-3 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.6 Pre-Stressed Concrete Containment Tendon Surveillance Program (continued) accordance with Section XI, Subsection IWL of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR50.55a, except where an alternative, exemption, or relief has been authorized by the NRC.

The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies. ]

5.5.7 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendation of Regulatory position c.4.b of Regulatory Guide 1.14, Revision 1, August 1975.

5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Codes) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda terminology for inservice performing inservice testing testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities,

c. The provisions of SR 3.0.3 are applicable to inservice testing activities, and

d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

Babcock & Wilcox STS 5.5-5 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials.

Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the Steam Generator Program].

Babcock & Wilcox STS 5.5-6 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program (continued)

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding [40%] of the nominal tube wall thickness shall be plugged [or repaired].

REVIEWER'S NOTE----------------------------------------

Alternate tube repair criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube repair criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube repair criteria.

[The following alternate tube repair criteria may be applied as an alternative to the 40% depth based criteria:

1. . . .]

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

REVIEWER'S NOTE-------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

Babcock & Wilcox STS 5.5-7 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program (continued)

[2. Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.]

[2. Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

[2. Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.]

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

[f. Provisions for SG tube repair methods. Steam generator tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

Babcock & Wilcox STS 5.5-8 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1. . . .]

5.5.109 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a. Identification of a sampling schedule for the critical variables and control points for these variables,

b. Identification of the procedures used to measure the values of the critical variables,

c. Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage,

d. Procedures for the recording and management of data,

e. Procedures defining corrective actions for all off control point chemistry conditions, and

f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

5.5.1011 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in [Regulatory Guide], and in accordance with [Regulatory Guide 1.52, Revision 2, ASME N510-1989, and AG-1].

a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < [0.05]% when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below

[+/- 10%].

Babcock & Wilcox STS 5.5-9 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1011 Ventilation Filter Testing Program (continued)

ESF Ventilation System Flowrate

[ ] [ ]

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < [0.05]% when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below [+/- 10%].

ESF Ventilation System Flowrate

[ ] [ ]

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in [Regulatory Guide 1.52, Revision 2], shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30°C (86°F) and the relative humidity specified below.

ESF Ventilation System Penetration RH Face Velocity

[ ] [See Reviewer's [See [See Reviewer's Note] Reviewer's Note]

Note]

REVIEWER'S NOTE----------------------------------------

The use of any standard other than ASTM D3803-1989 to test the charcoal sample may result in an overestimation of the capability of the charcoal to adsorb radioiodine. As a result, the ability of the charcoal filters to perform in a manner consistent with the licensing basis for the facility is indeterminate.

ASTM D 3803-1989 is a more stringent testing standard because it does not differentiate between used and new charcoal, it has a longer equilibration period performed at a temperature of 30°C (86°F) and a relative humidity (RH) of 95%

(or 70% RH with humidity control), and it has more stringent tolerances that improve repeatability of the test.

Allowable Penetration = [(100% - Methyl Iodide Efficiently

for Charcoal Credited in Licensee's Accident Analysis) / Safety Factor]

When ASTM D3803-1989 is used with 30°C (86°F) and 95% RH (or 70% RH with humidity control) is used, the staff will accept the following:

Safety factor 2 for systems with or without humidity control.

Babcock & Wilcox STS 5.5-10 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1011 Ventilation Filter Testing Program (continued)

Humidity control can be provided by heaters or an NRC-approved analysis that demonstrates that the air entering the charcoal will be maintained less than or equal to 70 percent RH under worst-case design-basis conditions.

If the system has a face velocity greater than 110 percent of 0.203 m/s (40 ft/min), the face velocity should be specified.

This value should be the efficiency that was incorporated in the licensee's accident analysis which was reviewed and approved by the staff in a safety evaluation.

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below [+/- 10%].

ESF Ventilation System Delta P Flowrate

[ ] [ ] [ ]

[ e. Demonstrate that the heaters for each of the ESF systems dissipate the value specified below [+/- 10%] when tested in accordance with

[ASME N510-1989].

ESF Ventilation System Wattage ]

[ ] [ ]

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.1112 [ Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the [Waste Gas Holdup System], [the quantity of radioactivity contained in gas storage tanks or fed into the offgas treatment system, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks]. The gaseous radioactivity quantities shall be determined following the methodology in [Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure"]. The liquid radwaste quantities shall be determined in accordance with [Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures"].

Babcock & Wilcox STS 5.5-11 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1112 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

The program shall include:

a. The limits for concentrations of hydrogen and oxygen in the [Waste Gas Holdup System] and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion),

b. A surveillance program to ensure that the quantity of radioactivity contained in [each gas storage tank and fed into the offgas treatment system] is less than the amount that would result in a whole body exposure of 0.5 rem to any individual in an unrestricted area, in the event of [an uncontrolled release of the tanks' contents], and

c. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the [Liquid Radwaste Treatment System] is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies. ]

5.5.1113 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1. An API gravity or an absolute specific gravity within limits,

2. A flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3. A clear and bright appearance with proper color or a water and sediment content within limits, Babcock & Wilcox STS 5.5-12 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1213 Diesel Fuel Oil Testing Program (continued)

b. Within 31 days following addition of the new fuel oil to storage tanks, verify that the properties of the new fuel oil, other than those addressed in a.,

above, are within limits for ASTM 2D fuel oil, and

c. Total particulate concentration of the fuel oil is 10 mg/l when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program testing frequencies.

5.5.1314 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. A change in the TS incorporated in the license or

2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that meet the criteria of 5.5.13.4b above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.1415 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

Babcock & Wilcox STS 5.5-13 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1415 Safety Function Determination Program (continued)

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected,

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists,

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities, and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power, or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and

a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable, or

b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable, or

c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.1516 Containment Leakage Rate Testing Program

[OPTION A]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option A, as modified by approved exemptions.

b. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]%

of containment air weight per day.

Babcock & Wilcox STS 5.5-14 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1516 Containment Leakage Rate Testing Program (continued)

c. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criterion is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and < 0.75 La for Type A tests.

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is [0.05 La] when tested at Pa.

b) For each door, leakage rate is [0.01 La] when pressurized to

[ 10 psig].

d. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

e. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

[OPTION B]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September, 1995, as modified by the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

[ 3. ...]

Babcock & Wilcox STS 5.5-15 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1516 Containment Leakage Rate Testing Program (continued)

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is [45 psig]. The containment design pressure is

[50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]%

of containment air weight per day.

d. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criterion is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and 0.75 La for Type A tests.

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is [0.05 La] when tested at Pa.

b) For each door, leakage rate is [0.01 La] when pressurized to

[ 10 psig].

e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

[OPTION A/B Combined]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J. [Type A][Type B and C] test requirements are in accordance with 10 CFR 50, Appendix J, Option A, as modified by approved exemptions. [Type B and C][Type A]

test requirements are in accordance with 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. The 10 CFR 50, Appendix J, Option B test requirements shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September, 1995, as modified by the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

Babcock & Wilcox STS 5.5-16 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1516 Containment Leakage Rate Testing Program (continued)

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

[ 3. ...]

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is [45 psig]. The containment design pressure is

[50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]%

of containment air weight per day.

d. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criterion is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and [< 0.75 La for Option A Type A tests] [ 0.75 La for Option B Type A tests].

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is [0.05 La] when tested at Pa.

b) For each door, leakage rate is [0.01 La] when pressurized to

[ 10 psig].

e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J Babcock & Wilcox STS 5.5-17 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1617 Battery Monitoring and Maintenance Program

REVIEWERS NOTE------------------------------------------

This program and the corresponding requirements in LCO 3.8.4, LCO 3.8.5, and LCO 3.8.6 require providing the information and verifications requested in the Notice of Availability for TSTF-500, Revision 2, "DC Electrical Rewrite - Update to TSTF-360," (76FR54510).

This Program provides controls for battery restoration and maintenance. The program shall be in accordance with IEEE Standard (Std) 450-2002, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," as endorsed by Regulatory Guide 1.129, Revision 2 (RG), with RG exceptions and program provisions as identified below:

a. The program allows the following RG 1.129, Revision 2 exceptions:

1. Battery temperature correction may be performed before or after conducting discharge tests.

2. RG 1.129, Regulatory Position 1, Subsection 2, "References," is not applicable to this program.

3. In lieu of RG 1.129, Regulatory Position 2, Subsection 5.2, "Inspections," the following shall be used: "Where reference is made to the pilot cell, pilot cell selection shall be based on the lowest voltage cell in the battery."

4 In Regulatory Guide 1.129, Regulatory Position 3, Subsection 5.4.1, "State of Charge Indicator," the following statements in paragraph (d) may be omitted: "When it has been recorded that the charging current has stabilized at the charging voltage for three consecutive hourly measurements, the battery is near full charge. These measurements shall be made after the initially high charging current decreases sharply and the battery voltage rises to approach the charger output voltage."

5. In lieu of RG 1.129, Regulatory Position 7, Subsection 7.6, "Restoration", the following may be used: "Following the test, record the float voltage of each cell of the string."

b. The program shall include the following provisions:

1. Actions to restore battery cells with float voltage < [2.13] V; Babcock & Wilcox STS 5.5-18 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1617 Battery Monitoring and Maintenance Program (continued)

2. Actions to determine whether the float voltage of the remaining battery cells is [2.13] V when the float voltage of a battery cell has been found to be < [2.13] V;

3. Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the plates;

4. Limits on average electrolyte temperature, battery connection resistance, and battery terminal voltage; and

5. A requirement to obtain specific gravity readings of all cells at each discharge test, consistent with manufacturer recommendations.

5.5.1718 Control Room Envelope (CRE) Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Air Cleanup System (CREACS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of [5 rem whole body or its equivalent to any part of the body] [5 rem total effective dose equivalent (TEDE)] for the duration of the accident. The program shall include the following elements:

a. The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.

[The following are exceptions to Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0:

1. ;and]

Babcock & Wilcox STS 5.5-19 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1718 Control Room Envelope (CRE) Habitability Program (continued)

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CREACS, operating at the flow rate required by the VFTP, at a Frequency of [18] months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the

[18] month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

5.5.1819 [ Setpoint Control Program This program shall establish the requirements for ensuring that setpoints for automatic protective devices are initially within and remain within the assumptions of the applicable safety analyses, provides a means for processing changes to instrumentation setpoints, and identifies setpoint methodologies to ensure instrumentation will function as required. The program shall ensure that testing of automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1)(ii)(A) verifies that instrumentation will function as required.

a. The program shall list the Functions in the following specifications to which it applies:

1. LCO 3.3.1, Reactor Protection System (RPS) Instrumentation;

2. LCO 3.3.3, Reactor Protection System (RPS) - Reactor Trip Module (RTM);

3. LCO 3.3.4, CONTROL ROD Drive (CRD) Trip Devices;

4. LCO 3.3.5, Engineered Safety Feature Actuation System (ESFAS)

Instrumentation;

5. LCO 3.3.8, Emergency Diesel Generator (EDG) Loss of Power Start (LOPS);

6. LCO 3.3.9, Source Range Neutron Flux;

7. LCO 3.3.10, Intermediate Range Neutron Flux; Babcock & Wilcox STS 5.5-20 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1819 Setpoint Control Program (continued)

8. LCO 3.3.11, Emergency Feedwater Initiation and Control (EFIC)

System Instrumentation;

9. LCO 3.3.15, Reactor Building (RB) Purge Isolation - High Radiation;

10. LCO 3.3.16, Control Room Isolation - High Radiation.

b. The program shall require the [Limiting Trip Setpoint (LTSP)], [Nominal Trip Setpoint (NTSP)], Allowable Value (AV), As-Found Tolerance (AFT), and As-Left Tolerance (ALT) (as applicable) of the Functions described in paragraph a. are calculated using the NRC approved setpoint methodology, as listed below. In addition, the program shall contain the value of the

[LTSP], [NTSP], AV, AFT, and ALT (as applicable) for each Function described in paragraph a. and shall identify the setpoint methodology used to calculate these values.

Reviewer's Note ---------------------------------------

List the NRC safety evaluation report by letter, date, and ADAMS accession number (if available) that approved the setpoint methodologies.

1. [Insert reference to NRC safety evaluation that approved the setpoint methodology.]

c. The program shall establish methods to ensure that Functions described in paragraph a. will function as required by verifying the as-left and as-found settings are consistent with those established by the setpoint methodology.

d. -----------------------------------REVIEWERS NOTE-------------------------------------

A license amendment request to implement a Setpoint Control Program must list the instrument functions to which the program requirements of paragraph d. will be applied. Paragraph d. shall apply to all Functions in the Reactor Protection System and Engineered Safety Feature Actuation System specifications unless one or more of the following exclusions apply:

1. Manual actuation circuits, automatic actuation logic circuits or to instrument functions that derive input from contacts which have no associated sensor or adjustable device, e.g., limit switches, breaker position switches, manual actuation switches, float switches, proximity detectors, etc. are excluded. In addition, those permissives and interlocks that derive input from a sensor or adjustable device that is tested as part of another TS function are excluded.

2. Settings associated with safety relief valves are excluded. The performance of these components is already controlled (i.e., trended with as-left and as-found limits) under the ASME Code for Operation and Maintenance of Nuclear Power Plants testing program.

Babcock & Wilcox STS 5.5-21 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1819 Setpoint Control Program (continued)

3. Functions and Surveillance Requirements which test only digital components are normally excluded. There is no expected change in result between SR performances for these components. Where separate as-left and as-found tolerance is established for digital component SRs, the requirements would apply.

The program shall identify the Functions described in paragraph a. that are automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1)(ii)(A). The [LTSP] of these Functions are Limiting Safety System Settings. These Functions shall be demonstrated to be functioning as required by applying the following requirements during CHANNEL CALIBRATIONS and CHANNEL FUNCTIONAL TESTS that verify the [LTSP or NTSP].

1 The as-found value of the instrument channel trip setting shall be compared with the previous as-left value or the specified [LTSP or NTSP].

2. If the as-found value of the instrument channel trip setting differs from the previous as-left value or the specified [LTSP or NTSP] by more than the pre-defined test acceptance criteria band (i.e., the specified AFT), then the instrument channel shall be evaluated before declaring the SR met and returning the instrument channel to service. This condition shall be entered in the plant corrective action program.

3. If the as-found value of the instrument channel trip setting is less conservative than the specified AV, then the SR is not met and the instrument channel shall be immediately declared inoperable.

4. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the [LTSP or NTSP] at the completion of the surveillance test; otherwise, the channel is inoperable (setpoints may be more conservative than the [LTSP or NTSP] provided that the as-found and as-left tolerances apply to the actual setpoint used to confirm channel performance).

e. The program shall be specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference]. ]

Babcock & Wilcox STS 5.5-22 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1920 [ Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.

b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program. ]

Babcock & Wilcox STS 5.5-23 Rev. 4.0

TSTF-545, Rev. 0 LCO APPLICABILITY B 3.0 BASES LCO 3.0.6 LCO 3.0.6 establishes an exception to LCO 3.0.2 for supported systems that have a support system LCO specified in the Technical Specifications (TS). This exception is provided because LCO 3.0.2 would require that the Conditions and Required Actions of the associated inoperable supported system LCO be entered solely due to the inoperability of the support system. This exception is justified because the actions that are required to ensure the unit is maintained in a safe condition are specified in the support system LCO's Required Actions. These Required Actions may include entering the supported system's Conditions and Required Actions or may specify other Required Actions.

When a support system is inoperable and there is an LCO specified for it in the TS, the supported system(s) are required to be declared inoperable if determined to be inoperable as a result of the support system inoperability. However, it is not necessary to enter into the supported systems' Conditions and Required Actions unless directed to do so by the support system's Required Actions. The potential confusion and inconsistency of requirements related to the entry into multiple support and supported systems' LCOs' Conditions and Required Actions are eliminated by providing all the actions that are necessary to ensure the unit is maintained in a safe condition in the support system's Required Actions.

However, there are instances where a support system's Required Action may either direct a supported system to be declared inoperable or direct entry into Conditions and Required Actions for the supported system.

This may occur immediately or after some specified delay to perform some other Required Action. Regardless of whether it is immediate or after some delay, when a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

Specification 5.5.1415, "Safety Function Determination Program (SFDP),"

ensures loss of safety function is detected and appropriate actions are taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other limitations, remedial actions, or compensatory actions may be identified as a result of the support system inoperability and corresponding exception to entering supported system Conditions and Required Actions. The SFDP implements the requirements of LCO 3.0.6.

Babcock & Wilcox STS B 3.0-8 Rev. 4.0

TSTF-545, Rev. 0 SR Applicability B 3.0 BASES SR 3.0.2 (continued)

The 25% extension does not significantly degrade the reliability that results from performing the Surveillance at its specified Frequency. This is based on the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the SRs. The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply.

These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. An eExamples of where SR 3.0.2 does not apply are is in the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the American Society of Mechanical Engineers (ASME) Code inservice testing required by 10 CFR 50.55a. Theseis programs establishes testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a test interval specified in the regulations directly or by reference.

As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "once per ..." basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable equipment in an alternative manner.

The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified.

SR 3.0.3 SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been performed in accordance with SR 3.0.2, and not at the time that the specified Frequency was not met.

Babcock & Wilcox STS B 3.0-18 Rev. 4.0

TSTF-545, Rev. 0 Pressurizer Safety Valves B 3.4.10 BASES LCO (continued) condition. Only one valve at a time will be removed from service for testing. The [36] hour exception is based on an 18 hour2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months outage time for each of the two valves. The 18 hour2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months period is derived from operating experience that hot testing can be performed in this timeframe.

ACTIONS A.1 With one pressurizer safety valve inoperable, restoration must take place within 15 minutes. The Completion Time of 15 minutes reflects the importance of maintaining the RCS overpressure protection system. An inoperable safety valve coincident with an RCS overpressure event could challenge the integrity of the RCPB.

B.1 and B.2 If the Required Action cannot be met within the required Completion Time or if both pressurizer safety valves are inoperable, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 4 with any RCS cold leg temperature [283]°F within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowed is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems. Similarly, the [24] hours allowed is reasonable, based on operating experience, to reach MODE 4 without challenging plant systems. With any RCS cold leg temperature at or below [283]°F, overpressure protection is provided by LTOP. The change from MODE 1, 2, or 3 to MODE 4 reduces the RCS energy (core power and pressure), lowers the potential for large pressurizer insurges, and thereby removes the need for overpressure protection by two pressurizer safety valves.

SURVEILLANCE SR 3.4.10.1 REQUIREMENTS SRs are specified in the INSERVICE TESTING PROGRAM Inservice Testing Program. Pressurizer safety valves are to be tested in accordance with the requirements of the ASME Code (Ref. 1), which provides the activities and the Frequency necessary to satisfy the SRs.

No additional requirements are specified.

The pressurizer safety valve setpoint is +/- [3]% for OPERABILITY; however, the valves are reset to +/- 1% during the Surveillance to allow for drift.

REFERENCES 1. ASME Code for Operation and Maintenance of Nuclear Power Plants.

Babcock & Wilcox STS B 3.4.10-3 Rev. 4.0

TSTF-545, Rev. 0 RCS PIV Leakage B 3.4.14 BASES SURVEILLANCE REQUIREMENTS (continued)

For the two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves. If the PIVs are not individually leakage tested, one valve may have failed completely and not detected if the other valve in series meets the leakage requirement. In this situation, the protection provided by redundant valves would be lost.

Testing is to be performed every 9 months, but may be extended, if the plant does not go into MODE 5 for at least 7 days.

REVIEWERS NOTE-----------------------------------

If the testing is within the scope of the licensee's INSERVICE TESTING PROGRAMInservice Testing Program, the Frequency "In accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program" should be used. Otherwise, the periodic Frequency of [18] months or the reference to the Surveillance Frequency Control Program should be used.

[ The [18 month] Frequency is consistent with 10 CFR 50.55a(g) (Ref. 8) as contained in the INSERVICE TESTING PROGRAM Inservice Testing Program, is within frequency allowed by the American Society of Mechanical Engineers (ASME) Code (Ref. 7), and is based on the need to perform such surveillances under conditions that apply during an outage and the potential for an unplanned transient if the Surveillance were performed with the plant at power.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

[ In addition, testing must be performed once after the valve has been opened by flow or exercised to ensure tight reseating. PIVs disturbed in the performance of this Surveillance should also be tested unless documentation shows that an infinite testing loop cannot practically be avoided. Testing must be performed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after the valve has been reseated. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is a reasonable and practical time limit for performing this test after opening or reseating a valve. ]

Babcock & Wilcox STS B 3.4.14-5 Rev. 4.0

TSTF-545, Rev. 0 SG Tube Integrity B 3.4.17 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.17 Steam Generator (SG) Tube Integrity BASES BACKGROUND Steam generator (SG) tubes are small diameter, thin walled tubes that carry primary coolant through the primary to secondary heat exchangers.

The SG tubes have a number of important safety functions. Steam generator tubes are an integral part of the reactor coolant pressure boundary (RCPB) and, as such, are relied on to maintain the primary systems pressure and inventory. The SG tubes isolate the radioactive fission products in the primary coolant from the secondary system. In addition, as part of the RCPB, the SG tubes are unique in that they act as the heat transfer surface between the primary and secondary systems to remove heat from the primary system. This Specification addresses only the RCPB integrity function of the SG. The SG heat removal function is addressed by LCO 3.4.4, "RCS Loops - MODES 1 and 2," LCO 3.4.5, "RCS Loops - MODE 3," LCO 3.4.6, "RCS Loops - MODE 4," and LCO 3.4.7, "RCS Loops - MODE 5, Loops Filled."

SG tube integrity means that the tubes are capable of performing their intended RCPB safety function consistent with the licensing basis, including applicable regulatory requirements.

Steam generator tubing is subject to a variety of degradation mechanisms. Steam generator tubes may experience tube degradation related to corrosion phenomena, such as wastage, pitting, intergranular attack, and stress corrosion cracking, along with other mechanically induced phenomena such as denting and wear. These degradation mechanisms can impair tube integrity if they are not managed effectively.

The SG performance criteria are used to manage SG tube degradation.

Specification 5.5.89, "Steam Generator (SG) Program," requires that a program be established and implemented to ensure that SG tube integrity is maintained. Pursuant to Specification 5.5.89, tube integrity is maintained when the SG performance criteria are met. There are three SG performance criteria: structural integrity, accident induced leakage, and operational LEAKAGE. The SG performance criteria are described in Specification 5.5.89. Meeting the SG performance criteria provides reasonable assurance of maintaining tube integrity at normal and accident conditions.

The processes used to meet the SG performance criteria are defined by the Steam Generator Program Guidelines (Ref. 1).

Babcock & Wilcox STS B 3.4.17-1 Rev. 4.0

TSTF-545, Rev. 0 SG Tube Integrity B 3.4.17 BASES APPLICABLE The steam generator tube rupture (SGTR) accident is the limiting design SAFETY basis event for SG tubes and avoiding an SGTR is the basis for this ANALYSES Specification. The analysis of a SGTR event assumes a bounding primary to secondary LEAKAGE rate equal to the operational LEAKAGE rate limits in LCO 3.4.13, "RCS Operational LEAKAGE," plus the leakage rate associated with a double-ended rupture of a single tube. The accident analysis for a SGTR assumes the contaminated secondary fluid is only briefly released to the atmosphere via safety valves and the majority is discharged to the main condenser.

The analysis for design basis accidents and transients other than a SGTR assume the SG tubes retain their structural integrity (i.e., they are assumed not to rupture.) In these analyses, the steam discharge to the atmosphere is based on the total primary to secondary LEAKAGE from all SGs of [1 gallon per minute] or is assumed to increase to [1 gallon per minute] as a result of accident induced conditions. For accidents that do not involve fuel damage, the primary coolant activity level of DOSE EQUIVALENT I-131 is assumed to be equal to the LCO 3.4.16, "RCS Specific Activity," limits. For accidents that assume fuel damage, the primary coolant activity is a function of the amount of activity released from the damaged fuel. The dose consequences of these events are within the limits of GDC 19 (Ref. 2), 10 CFR 100 (Ref. 3) or the NRC approved licensing basis (e.g., a small fraction of these limits).

Steam generator tube integrity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).

LCO The LCO requires that SG tube integrity be maintained. The LCO also requires that all SG tubes that satisfy the repair criteria be plugged [or repaired] in accordance with the Steam Generator Program.

During an SG inspection, any inspected tube that satisfies the Steam Generator Program repair criteria is [repaired or] removed from service by plugging. If a tube was determined to satisfy the repair criteria but was not plugged [or repaired], the tube may still have tube integrity.

In the context of this Specification, a SG tube is defined as the entire length of the tube, including the tube wall [and any repairs made to it],

between the tube-to-tubesheet weld at the tube inlet and the tube-to-tubesheet weld at the tube outlet. The tube-to-tubesheet weld is not considered part of the tube.

A SG tube has tube integrity when it satisfies the SG performance criteria.

The SG performance criteria are defined in Specification 5.5.89, "Steam Generator Program," and describe acceptable SG tube performance.

The Steam Generator Program also provides the evaluation process for determining conformance with the SG performance criteria.

Babcock & Wilcox STS B 3.4.17-2 Rev. 4.0

TSTF-545, Rev. 0 SG Tube Integrity B 3.4.17 BASES SURVEILLANCE REQUIREMENTS (continued)

The Steam Generator Program determines the scope of the inspection and the methods used to determine whether the tubes contain flaws satisfying the tube repair criteria. Inspection scope (i.e., which tubes or areas of tubing within the SG are to be inspected) is a function of existing and potential degradation locations. The Steam Generator Program also specifies the inspection methods to be used to find potential degradation.

Inspection methods are a function of degradation morphology, non-destructive examination (NDE) technique capabilities, and inspection locations.

The Steam Generator Program defines the Frequency of SR 3.4.17.1.

The Frequency is determined by the operational assessment and other limits in the SG examination guidelines (Ref. 6). The Steam Generator Program uses information on existing degradations and growth rates to determine an inspection Frequency that provides reasonable assurance that the tubing will meet the SG performance criteria at the next scheduled inspection. In addition, Specification 5.5.89 contains prescriptive requirements concerning inspection intervals to provide added assurance that the SG performance criteria will be met between scheduled inspections.

SR 3.4.17.2 During an SG inspection, any inspected tube that satisfies the Steam Generator Program repair criteria is [repaired or] removed from service by plugging. The tube repair criteria delineated in Specification 5.5.89 are intended to ensure that tubes accepted for continued service satisfy the SG performance criteria with allowance for error in the flaw size measurement and for future flaw growth. In addition, the tube repair criteria, in conjunction with other elements of the Steam Generator Program, ensure that the SG performance criteria will continue to be met until the next inspection of the subject tube(s). Reference 1 provides guidance for performing operational assessments to verify that the tubes remaining in service will continue to meet the SG performance criteria.

[Steam generator tube repairs are only performed using approved repair methods as described in the Steam Generator Program.]

The Frequency of prior to entering MODE 4 following a SG inspection ensures that the Surveillance has been completed and all tubes meeting the repair criteria are plugged [or repaired] prior to subjecting the SG tubes to significant primary to secondary pressure differential.

Babcock & Wilcox STS B 3.4.17-6 Rev. 4.0

TSTF-545, Rev. 0 ECCS - Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.3 With the exception of systems in operation, the ECCS pumps are normally in a standby, nonoperating mode. As such, the flow path piping has the potential to develop voids and pockets of entrained gases.

Maintaining the piping from the ECCS pumps to the RCS full of water ensures that the system will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent water hammer, pump cavitation, and pumping of noncondensible gas (e.g., air, nitrogen, or hydrogen) into the reactor vessel following an ESFAS signal or during shutdown cooling. [ The 31 day Frequency takes into consideration the gradual nature of gas accumulation in the ECCS piping and the existence of procedural controls governing system operation.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.5.2.4 Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME Code (Ref. 6). This type of testing may be accomplished by measuring the pump's developed head at only one point of the pump's characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the plant accident analysis. SRs are specified in the INSERVICE TESTING PROGRAM Inservice Testing Program of the ASME Code. The ASME Code provides the activities and Frequencies necessary to satisfy the requirements.

Babcock & Wilcox STS B 3.5.2-8 Rev. 4.0

TSTF-545, Rev. 0 ECCS - Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.5 and SR 3.5.2.6 These SRs demonstrate that each automatic ECCS valve actuates to the required position on an actual or simulated ESFAS signal and that each ECCS pump starts on receipt of an actual or simulated ESFAS signal.

This SR is not required for valves that are locked, sealed, or otherwise secured in position under administrative controls. [ The 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. The 18 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

The actuation logic is tested as part of the ESFAS testing, and equipment performance is monitored as part of the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.5.2.7 This Surveillance ensures that these valves are in the proper position to prevent the HPI pump from exceeding its runout limit. [ This 18 month Frequency is based on the same reasons as those stated for SR 3.5.2.5 and SR 3.5.2.6.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

Babcock & Wilcox STS B 3.5.2-9 Rev. 4.0

TSTF-545, Rev. 0 Containment Isolation Valves B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) required to meet the SR during the time they are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.

The Note allows valves and blind flanges located in high radiation areas to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since the access to these areas is typically restricted during MODES 1, 2, 3, and 4 for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in their proper position, is small.

SR 3.6.3.5 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses.

REVIEWERS NOTE-----------------------------------

If the testing is within the scope of the licensee's INSERVICE TESTING PROGRAM Inservice Testing Program, the Frequency "In accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program" should be used. Otherwise, the periodic Frequency of [92] days or the reference to the Surveillance Frequency Control Program should be used.

[ The Frequency of this SR is in accordance with [the INSERVICE TESTING PROGRAM Inservice Testing Program] [92 days.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.] ]

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

Babcock & Wilcox STS B 3.6.3-15 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems B 3.6.6 BASES SURVEILLANCE REQUIREMENTS (continued)

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6.3 Verifying that each [required] containment cooling train provides an essential raw water cooling flow rate of [1780] gpm to each cooling unit provides assurance that the design flow rate assumed in the safety analyses will be achieved (Ref. 1). [ The Frequency was developed considering the known reliability of the Cooling Water System, the two train redundancy available, and the low probability of a significant degradation of flow occurring between surveillances.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6.4 Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref. 7). Since the Containment Spray System pumps cannot be tested with flow through the Babcock & Wilcox STS B 3.6.6-9 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems B 3.6.6 BASES SURVEILLANCE REQUIREMENTS (continued) spray headers, they are tested on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.6.6.5 and SR 3.6.6.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated actuation signal. This SR is not required for valves that are locked, sealed, or otherwise secured in position under administrative controls. [ The [18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillances when performed at the [18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6.7 This SR requires verification that each [required] containment cooling train actuates upon receipt of an actual or simulated actuation signal.

[ The [18] month Frequency is based on engineering judgment and has been shown to be acceptable through operating experience. See SR 3.6.6.5 and SR 3.6.6.6, above, for further discussion of the basis for the [18] month Frequency.

Babcock & Wilcox STS B 3.6.6-10 Rev. 4.0

TSTF-545, Rev. 0 MSSVs B 3.7.1 BASES LCO The MSSVs setpoints are established to prevent overpressurization as discussed in the Applicable Safety Analysis section of these Bases. The LCO requires all MSSVs to be OPERABLE to ensure compliance with the ASME Code following DBAs initiated at full power. Operation with less than a full complement of MSSVs requires limitations on unit THERMAL POWER and adjustment of the Reactor Protection System (RPS) trip setpoints. This effectively limits the Main Steam System steam flow while the MSSV relieving capacity is reduced due to valve inoperability. To be OPERABLE, lift setpoints must remain within limits, according to Table 3.7.1-1 in the accompanying LCO.

The OPERABILITY of the MSSVs is defined as the ability to open within the setpoint tolerances, relieve steam generator overpressure, and reseat when pressure has been reduced.

The OPERABILITY of the MSSVs is determined by periodic surveillance testing in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

The lift settings, according to Table 3.7.1-1 in the accompanying LCO, correspond to ambient conditions of the valve at nominal operating temperature and pressure.

This LCO provides assurance that the MSSVs will perform the design safety function to mitigate the consequences of accidents that could result in a challenge to the RCPB.

APPLICABILITY In MODE 1 above [18]% RTP, the number of MSSVs per steam generator required to be OPERABLE must be within the acceptable region, according to Figure 3.7.1-1 in the accompanying LCO. Below [18]% RTP in MODES 1, 2, and 3, only two MSSVs are required OPERABLE per steam generator.

In MODES 4 and 5, there is no credible transient requiring the MSSVs.

The steam generators are not normally used for heat removal in MODES 5 and 6, and thus cannot be overpressurized; there is no requirement for the MSSVs to be OPERABLE in these MODES.

ACTIONS The ACTIONS Table is modified by a Note indicating that separate Condition entry is allowed for each MSSV.

Babcock & Wilcox STS B 3.7.1-2 Rev. 4.0

TSTF-545, Rev. 0 MSSVs B 3.7.1 BASES ACTIONS (continued) reduce the setpoints. The Completion Time of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months for Required Action A.2 is based on a reasonable time to correct the MSSV inoperability, the time required to perform the power reduction, operating experience in resetting all channels of a protective function, and on the low probability of the occurrence of a transient that could result in steam generator overpressure during this period.

B.1 and B.2 With one or more MSSVs inoperable, a verification by administrative means that at least [two] required MSSVs per steam generator are OPERABLE, with each valve from a different lift setting range, is performed.

If the MSSVs cannot be restored to OPERABLE status in the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

SURVEILLANCE SR 3.7.1.1 REQUIREMENTS This SR verifies the OPERABILITY of the MSSVs by the verification of each MSSV lift setpoint in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. The ASME Code (Ref. 4) requires that safety and relief valve tests be performed in accordance with ANSI/ASME OM-1-1987 (Ref. 5). According to Reference 5, the following tests are required for MSSVs:

a. Visual examination,

b. Seat tightness determination,

c. Setpoint pressure determination (lift setting),

d. Compliance with owner's seat tightness criteria, and

e. Verification of the balancing device integrity device on balanced valves.

Babcock & Wilcox STS B 3.7.1-4 Rev. 4.0

TSTF-545, Rev. 0 MSIVs B 3.7.2 BASES SURVEILLANCE SR 3.7.2.1 REQUIREMENTS This SR verifies that the closure time of each MSIV is within the limit given in Reference 5 and is within that assumed in the accident and containment analyses. This SR also verifies the valve closure time is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. This SR is normally performed upon returning the unit to operation following a refueling outage, because the MSIVs should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. As the MSIVs are not to be tested at power, they are exempt from the ASME Code (Ref. 6) requirements during operation in MODES 1 and 2.

The Frequency for this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

This test is conducted in MODE 3, with the unit at operating temperature and pressure. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. This allows delaying testing until MODE 3 in order to establish conditions consistent with those under which the acceptance criterion was generated.

SR 3.7.2.2 This SR verifies that each MSIV can close on an actual or simulated actuation signal. This Surveillance is normally performed upon returning the plant to operation following a refueling outage. [ The Frequency of MSIV testing is every [18] months. The [18] month Frequency for testing is based on the refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the

[18] month Frequency. Therefore, this Frequency is acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

Babcock & Wilcox STS B 3.7.2-5 Rev. 4.0

TSTF-545, Rev. 0

[MFSVs, MFCVs, and Associated SFCVs]

B 3.7.3 BASES SURVEILLANCE SR 3.7.3.1 REQUIREMENTS This SR verifies that the closure time of each [MFSV], [MFCV], and

[associated SFCV] is within the limit given in Reference 2 and is within that assumed in the accident and containment analyses. This SR also verifies the valve closure time is in accordance with the INSERVICE TESTING PROGRAMInservice Testing Program. This SR is normally performed upon returning the unit to operation following a refueling outage. The [MFSV], [MFCV], and [associated SFCV] should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the ASME Code (Ref. 3) requirements during operation in MODES 1 and 2.

This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR.

The Frequency for this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.7.3.2 This SR verifies that each [MFSV, MFCV, and associated SFCV] can close on an actual or simulated actuation signal. This Surveillance is normally performed upon returning the plant to operation following a refueling outage.

[ The Frequency for this SR is every [18] months. The [18] month Frequency for testing is based on the refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the [18] month Frequency. Therefore, this Frequency is acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

Babcock & Wilcox STS B 3.7.3-5 Rev. 4.0

TSTF-545, Rev. 0 EFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued) to locking, sealing, or securing. This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves. This Surveillance does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position.

[ The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.7.5.2 Verifying that each EFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that EFW pump performance has not degraded during the cycle. Flow and differential head are normal tests of pump performance required by the ASME Code (Ref. 3). Because it is undesirable to introduce cold EFW into the steam generators while they are operating, this test is performed on recirculation flow.

This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. Performance of inservice testing as discussed in the ASME Code (Ref. 3) and the INSERVICE TESTING PROGRAM, at 3 month intervals, satisfies this requirement.

This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions are established. This deferral is required because there is insufficient steam pressure to perform the test.

Babcock & Wilcox STS B 3.7.5-7 Rev. 4.0

TSTF-545, Rev. 0 Battery Parameters B 3.8.6 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.6 Battery Parameters BASES BACKGROUND This LCO delineates the limits on battery float current as well as electrolyte temperature, level, and float voltage for the DC power subsystem batteries. A discussion of these batteries and their OPERABILITY requirements is provided in the Bases for LCO 3.8.4, "DC Sources - Operating," and LCO 3.8.5, "DC Sources - Shutdown." In addition to the limitations of this Specification, the [licensee controlled program] also implements a program specified in Specification 5.5.1617 for monitoring various battery parameters.

The battery cells are of flooded lead acid construction with a nominal specific gravity of [1.215]. This specific gravity corresponds to an open circuit battery voltage of approximately 120 V for [58] cell battery (i.e., cell voltage of [2.065] volts per cell (Vpc)). The open circuit voltage is the voltage maintained when there is no charging or discharging. Once fully charged with its open circuit voltage [2.065] Vpc, the battery cell will maintain its capacity for [30] days without further charging per manufacturer's instructions. Optimal long term performance however, is obtained by maintaining a float voltage [2.20 to 2.25] Vpc. This provides adequate over-potential which limits the formation of lead sulfate and self discharge. The nominal float voltage of [2.22] Vpc corresponds to a total float voltage output of [128.8] V for a [58] cell battery as discussed in the FSAR, Chapter [8] (Ref. 2).

APPLICABLE The initial conditions of Design Basis Accident (DBA) and transient SAFETY analyses in the FSAR, Chapter [6] (Ref. 3) and Chapter [15] (Ref. 4),

ANALYSES assume Engineered Safety Feature systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the DGs, emergency auxiliaries, and control and switching during all MODES of operation.

The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the unit. This includes maintaining at least one subsystem of DC sources OPERABLE during accident conditions, in the event of:

a. An assumed loss of all offsite AC power or all onsite AC power and

b. A worst-case single failure.

Battery parameters satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).

Babcock & Wilcox STS B 3.8.6-1 Rev. 4.0

TSTF-545, Rev. 0 Battery Parameters B 3.8.6 BASES LCO Battery parameters must remain within acceptable limits to ensure availability of the required DC power to shut down the reactor and maintain it in a safe condition after an anticipated operational occurrence or a postulated DBA. Battery parameter limits are conservatively established, allowing continued DC electrical system function even with limits not met. Additional preventative maintenance, testing, and monitoring performed in accordance with the [licensee controlled program] is conducted as specified in Specification 5.5.1617.

APPLICABILITY The battery parameters are required solely for the support of the associated DC electrical power subsystems. Therefore, battery parameter limits are only required when the DC power source is required to be OPERABLE. Refer to the Applicability discussion in Bases for LCO 3.8.4 and LCO 3.8.5.

ACTIONS A.1, A.2, and A.3 With one or more cells in one or more batteries in one subsystem

< [2.07] V, the battery cell is degraded. Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months verification of the required battery charger OPERABILITY is made by monitoring the battery terminal voltage (SR 3.8.4.1) and of the overall battery state of charge by monitoring the battery float charge current (SR 3.8.6.1). This assures that there is still sufficient battery capacity to perform the intended function.

Therefore, the affected battery is not required to be considered inoperable solely as a result of one or more cells in one or more batteries < [2.07] V, and continued operation is permitted for a limited period up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Since the Required Actions only specify "perform," a failure of SR 3.8.4.1 or SR 3.8.6.1 acceptance criteria does not result in this Required Action not met. However, if one of the SRs is failed the appropriate Condition(s),

depending on the cause of the failures, is entered. If SR 3.8.6.1 is failed then there is not assurance that there is still sufficient battery capacity to perform the intended function and the battery must be declared inoperable immediately.

B.1 and B.2 One or more batteries in one subsystem with float current > [2] amps indicates that a partial discharge of the battery capacity has occurred.

This may be due to a temporary loss of a battery charger or possibly due to one or more battery cells in a low voltage condition reflecting some loss of capacity. Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months verification of the required battery charger OPERABILITY is made by monitoring the battery terminal voltage. If the terminal voltage is found to be less than the minimum established float voltage there are two possibilities, the battery charger is inoperable or is operating in the current limit mode. Condition A addresses charger inoperability. If the charger is operating in the current limit mode after Babcock & Wilcox STS B 3.8.6-2 Rev. 4.0

TSTF-545, Rev. 0 Battery Parameters B 3.8.6 BASES ACTIONS (continued)

C.1, C.2, and C.3 With one or more batteries in one subsystem with one or more cells electrolyte level above the top of the plates, but below the minimum established design limits, the battery still retains sufficient capacity to perform the intended function. Therefore, the affected battery is not required to be considered inoperable solely as a result of electrolyte level not met. Within 31 days the minimum established design limits for electrolyte level must be re-established.

With electrolyte level below the top of the plates there is a potential for dryout and plate degradation. Required Actions C.1 and C.2 address this potential (as well as provisions in Specification 5.5.1617, Battery Monitoring and Maintenance Program). They are modified by a Note that indicates they are only applicable if electrolyte level is below the top of the plates. Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months level is required to be restored to above the top of the plates. The Required Action C.2 requirement to verify that there is no leakage by visual inspection and the Specification 5.5.1617.b item to initiate action to equalize and test in accordance with manufacturer's recommendation are taken from IEEE Standard 450. They are performed following the restoration of the electrolyte level to above the top of the plates. Based on the results of the manufacturer's recommended testing the batter[y][ies] may have to be declared inoperable and the affected cell[s] replaced.

D.1 With one or more batteries in one subsystem with pilot cell temperature less than the minimum established design limits, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is allowed to restore the temperature to within limits. A low electrolyte temperature limits the current and power available. Since the battery is sized with margin, while battery capacity is degraded, sufficient capacity exists to perform the intended function and the affected battery is not required to be considered inoperable solely as a result of the pilot cell temperature not met.

E.1 With one or more batteries in redundant subsystems with battery parameters not within limits there is not sufficient assurance that battery capacity has not been affected to the degree that the batteries can still perform their required function, given that redundant batteries are involved. With redundant batteries involved this potential could result in a Babcock & Wilcox STS B 3.8.6-4 Rev. 4.0

TSTF-545, Rev. 0 Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued) is not maintained the Required Actions of LCO 3.8.4 ACTION A are being taken, which provide the necessary and appropriate verifications of the battery condition. Furthermore, the float current limit of [2] amps is established based on the nominal float voltage value and is not directly applicable when this voltage is not maintained.

SR 3.8.6.2 and SR 3.8.6.5 Optimal long term battery performance is obtained by maintaining a float voltage greater than or equal to the minimum established design limits provided by the battery manufacturer, which corresponds to [130.5] V at the battery terminals, or [2.25] Vpc. This provides adequate over-potential, which limits the formation of lead sulfate and self discharge, which could eventually render the battery inoperable. Float voltages in this range or less, but greater than [2.07] Vpc, are addressed in Specification 5.5.1617. SRs 3.8.6.2 and 3.8.6.5 require verification that the cell float voltages are equal to or greater than the short term absolute minimum voltage of [2.07] V. [ The Frequency for cell voltage verification every 31 days for pilot cell and 92 days for each connected cell is consistent with IEEE-450 (Ref. 1).

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.8.6.3 The limit specified for electrolyte level ensures that the plates suffer no physical damage and maintains adequate electron transfer capability.

[ The Frequency of 31 days is consistent with IEEE-450 (Ref. 1).

OR Babcock & Wilcox STS B 3.8.6-6 Rev. 4.0

TSTF-545, Rev. 0 Containment Penetrations B 3.9.3 BASES SURVEILLANCE REQUIREMENTS (continued)

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

As such, this Surveillance ensures that a postulated fuel handling accident [involving handling recently irradiated fuel] that releases fission product radioactivity within the containment will not result in a release of significant fission product radioactivity to the environment in excess of those recommended by Standard Review Plan Section 15.7.4 (Ref. 3).

SR 3.9.3.2 This Surveillance demonstrates that each containment purge and exhaust valve actuates to its isolation position on manual initiation or on an actual or simulated high radiation signal. [ The 18 month Frequency maintains consistency with other similar ESFAS instrumentation and valve testing requirements. In LCO 3.3.15, "RB Purge Isolation - High Radiation," the isolation instrumentation requires a CHANNEL CHECK every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and a CHANNEL FUNCTIONAL TEST every 92 days to ensure the channel OPERABILITY during refueling operations. Every 18 months a CHANNEL CALIBRATION is performed. The system actuation response time is demonstrated every 18 months, during refueling, on a STAGGERED TEST BASIS.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.3.5 demonstrates that the isolation time of each valve is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program requirements. These Surveillances performed during MODE 6 will ensure that the valves are Babcock & Wilcox STS B 3.9.3-6 Rev. 4.0

TSTF-545, Rev. 0 Definitions 1.1 1.1 Definitions ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time interval from FEATURE (ESF) RESPONSE when the monitored parameter exceeds its actuation TIME setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water injection or 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 to the Secondary System (primary to secondary LEAKAGE);

b. Unidentified LEAKAGE All LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE, and

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

Westinghouse STS 1.1-3 Rev. 4.0

TSTF-545, Rev. 0 LCO Applicability 3.0 3.0 LCO Applicability LCO 3.0.4 (continued)

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with Specification 5.5.1415, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

LCO 3.0.7 Test Exception LCOs [3.1.8 and 3.4.19] allow specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Test Exception LCOs is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

Westinghouse STS 3.0-2 Rev. 4.0

TSTF-545, Rev. 0 Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE In accordance in accordance with the Inservice Testing Program. with the Following testing, lift settings shall be within +/- 1%. INSERVICE TESTING PROGRAM Inservice Testing Program Westinghouse STS 3.4.10-2 Rev. 4.0

TSTF-545, Rev. 0 RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 ------------------------------NOTES-----------------------------

1. Not required to be performed in MODES 3 and 4.

2. Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to In accordance 0.5 gpm per nominal inch of valve size up to a with the maximum of 5 gpm at an RCS pressure INSERVICE

[2215] psig and [2255] psig. TESTING PROGRAM Inservice Testing Program, and [

[18] months OR In accordance with the Surveillance Frequency Control Program ]

AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months AND Westinghouse STS 3.4.14-3 Rev. 4.0

TSTF-545, Rev. 0 RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve SR 3.4.14.2 -------------------------------NOTE------------------------------

[ Not required to be met when the RHR System autoclosure interlock is disabled in accordance with SR 3.4.12.7.

Verify RHR System autoclosure interlock prevents [ [18] months the valves from being opened with a simulated or actual RCS pressure signal [425] psig. OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.4.14.3 -------------------------------NOTE------------------------------

[ Not required to be met when the RHR System autoclosure interlock is disabled in accordance with SR 3.4.12.7.

Verify RHR System autoclosure interlock causes the [ [18] months valves to close automatically with a simulated or actual RCS pressure signal [600] psig. OR In accordance with the Surveillance Frequency Control Program ] ]

Westinghouse STS 3.4.14-4 Rev. 4.0

TSTF-545, Rev. 0 ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 [ Verify the following valves are in the listed position [ 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power to the valve operator removed.

OR Number Position Function

[ ] [ ] [ ] In accordance

[ ] [ ] [ ] with the

[ ] [ ] [ ] Surveillance Frequency Control Program ]

SR 3.5.2.2 Verify each ECCS manual, power operated, and [ 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the OR correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.5.2.3 [ Verify ECCS piping is full of water. [ 31 days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.5.2.4 Verify each ECCS pump's developed head at the In accordance test flow point is greater than or equal to the with the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program Westinghouse STS 3.5.2-2 Rev. 4.0

TSTF-545, Rev. 0 Containment Isolation Valves (Atmospheric, Subatmospheric, Ice Condenser, and Dual) 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.4 -------------------------------NOTE------------------------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment and MODE 4 from not locked, sealed, or otherwise secured and MODE 5 if not required to be closed during accident conditions is performed within closed, except for containment isolation valves that the previous are open under administrative controls. 92 days SR 3.6.3.5 Verify the isolation time of each automatic power [In accordance operated containment isolation valve is within limits. with the INSERVICE TESTING PROGRAM Inservice Testing Program OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.3.6 [ Cycle each weight or spring loaded check valve [ 92 days testable during operation through one complete cycle of full travel, and verify each check valve OR remains closed when the differential pressure in the direction of flow is [1.2] psid and opens when the In accordance differential pressure in the direction of flow is with the

[1.2] psid and < [5.0] psid. Surveillance Frequency Control Program ]

Westinghouse STS 3.6.3-9 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems (Atmospheric and Dual) 3.6.6A SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6A.3 Verify each [required] containment cooling train [ 31 days cooling water flow rate is [700] gpm.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6A.4 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with the the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.6.6A.5 Verify each automatic containment spray valve in [ [18] months the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position OR on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6A.6 Verify each containment spray pump starts [ [18] months automatically on an actual or simulated actuation signal. OR In accordance with the Surveillance Frequency Control Program ]

Westinghouse STS 3.6.6A-3 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems (Atmospheric and Dual) 3.6.6B SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6B.2 Operate each [required] containment cooling train [ 31 days fan unit for 15 minutes.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6B.3 Verify each [required] containment cooling train [ 31 days cooling water flow rate is [700] gpm.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6B.4 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with the the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.6.6B.5 Verify each automatic containment spray valve in [ [18] months the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position OR on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program ]

Westinghouse STS 3.6.6B-3 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray System (Ice Condenser) 3.6.6C SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6C.2 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with the the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.6.6C.3 Verify each automatic containment spray valve in [ [18] months the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position OR on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6C.4 Verify each containment spray pump starts [ [18] months automatically on an actual or simulated actuation signal. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6C.5 Verify each spray nozzle is unobstructed. [At first refueling]

AND

[ 10 years OR In accordance with the Surveillance Frequency Control Program ]

Westinghouse STS 3.6.6C-2 Rev. 4.0

TSTF-545, Rev. 0 QS System (Subatmospheric) 3.6.6D 3.6 CONTAINMENT SYSTEMS 3.6.6D Quench Spray (QS) System (Subatmospheric)

LCO 3.6.6D Two QS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One QS train inoperable. A.1 Restore QS train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

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 not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6D.1 Verify each QS manual, power operated, and [ 31 days automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the OR correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.6D.2 Verify each QS pump's developed head at the flow In accordance test point is greater than or equal to the required with the developed head. INSERVICE TESTING Westinghouse STS 3.6.6D-1 Rev. 4.0

TSTF-545, Rev. 0 QS System (Subatmospheric) 3.6.6D SURVEILLANCE FREQUENCY PROGRAM Inservice Testing Program Westinghouse STS 3.6.6D-2 Rev. 4.0

TSTF-545, Rev. 0 RS System (Subatmospheric) 3.6.6E SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6E.5 Verify each RS [and casing cooling] pump's In accordance developed head at the flow test point is greater than with the or equal to the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.6.6E.6 Verify on an actual or simulated actuation signal(s): [ [18] months

a. Each RS automatic valve in the flow path that is OR not locked, sealed, or otherwise secured in position, actuates to the correct position, In accordance with the

b. Each RS pump starts automatically, and Surveillance Frequency

c. [ Each casing cooling pump starts Control Program ]

automatically. ]

SR 3.6.6E.7 Verify each spray nozzle is unobstructed. [ At first refueling ]

AND

[ 10 years OR In accordance with the Surveillance Frequency Control Program ]

Westinghouse STS 3.6.6E-3 Rev. 4.0

TSTF-545, Rev. 0 Vacuum Relief Valves (Atmospheric and Ice Condenser) 3.6.12 3.6 CONTAINMENT SYSTEMS 3.6.12 Vacuum Relief Valves (Atmospheric and Ice Condenser)

LCO 3.6.12 [Two] vacuum relief lines shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One vacuum relief line A.1 Restore vacuum relief line 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. to OPERABLE status.

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 not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.12.1 Verify each vacuum relief line is OPERABLE in In accordance accordance with the Inservice Testing Program. with the INSERVICE TESTING PROGRAM Inservice Testing Program Westinghouse STS 3.6.12-1 Rev. 4.0

TSTF-545, Rev. 0 MSSVs 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2 --------------NOTE--------------

Only required in MODE 1.

Reduce the Power Range 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Neutron Flux - High reactor trip setpoint to less than or equal to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months One or more steam generators with [4]

MSSVs inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify each required MSSV lift setpoint per In accordance Table 3.7.1-2 in accordance with the INSERVICE with the TESTING PROGRAM Inservice Testing Program. INSERVICE Following testing, lift setting shall be within +1%. TESTING PROGRAM Inservice Testing Program Westinghouse STS 3.7.1-2 Rev. 4.0

TSTF-545, Rev. 0 MSIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify the isolation time of each MSIV is within In accordance limits. with the INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.7.2.2 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify each MSIV actuates to the isolation position [ [18] months on an actual or simulated actuation signal.

OR In accordance with the Surveillance Frequency Control Program ]

Westinghouse STS 3.7.2-2 Rev. 4.04.0

TSTF-545, Rev. 0 MFIVs and MFRVs and [Associated Bypass Valves]

3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two valves in the same D.1 Isolate affected flow path. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flow path inoperable.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. [ AND E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ]

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the isolation time of each MFIV, MFRV[, and In accordance associated bypass valve] is within limits. with the INSERVICE TESTING PROGRAM Inservice Testing Program SR 3.7.3.2 Verify each MFIV, MFRV[, and associated bypass [ [18] months valves] actuates to the isolation position on an actual or simulated actuation signal. OR In accordance with the Surveillance Frequency Control Program ]

Westinghouse STS 3.7.3-2 Rev. 4.0

TSTF-545, Rev. 0 AFW System 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required AFW train F.1 Initiate action to restore Immediately inoperable in MODE 4. AFW train to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 -------------------------------NOTE------------------------------

[ AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation. ]

Verify each AFW manual, power operated, and [ 31 days automatic valve in each water flow path, [and in both steam supply flow paths to the steam turbine driven OR pump,] that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance Frequency Control Program ]

SR 3.7.5.2 -------------------------------NOTE------------------------------

[ Not required to be performed for the turbine driven AFW pump until [24 hours] after [1000] psig in the steam generator. ]

Verify the developed head of each AFW pump at the In accordance flow test point is greater than or equal to the with the required developed head. INSERVICE TESTING PROGRAM Inservice Testing Program Westinghouse STS 3.7.5-3 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendations of Regulatory Position C.4.b of Regulatory Guide 1.14, Revision 1, August 1975.

In lieu of Position C.4.b(1) and C.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle one-half of the outer radius or a surface examination (MT and/or PT) of exposed surfaces of the removed flywheels may be conducted at 20 year intervals.

REVIEWER'S NOTE----------------------------------------

The inspection interval and scope for RCP flywheels stated above can be applied to plants that satisfy the requirements in WCAP-15666, "Extension of Reactor Coolant Pump Motor Flywheel Examination."

5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda performing terminology for inservice inservice testing testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities,

c. The provisions of SR 3.0.3 are applicable to inservice testing activities, and Westinghouse STS 5.5-5 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Inservice Testing Program (continued)

d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.89 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the as found condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to Westinghouse STS 5.5-6 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program (continued) exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the Steam Generator Program.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding [40%] of the nominal tube wall thickness shall be plugged [or repaired].

REVIEWER'S NOTE----------------------------------------

Alternate tube repair criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube repair criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube repair criteria.

[The following alternate tube repair criteria may be applied as an alternative to the 40% depth based criteria:

1. . . .]

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

Westinghouse STS 5.5-7 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

[2. Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.]

[2. Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

[2. Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.]

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

Westinghouse STS 5.5-8 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.89 Steam Generator (SG) Program (continued)

[f. Provisions for SG tube repair methods. Steam generator tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1. . . .]

5.5.910 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a. Identification of a sampling schedule for the critical variables and control points for these variables,

b. Identification of the procedures used to measure the values of the critical variables,

c. Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage,

d. Procedures for the recording and management of data,

e. Procedures defining corrective actions for all off control point chemistry conditions, and

f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

Westinghouse STS 5.5-9 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1011 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in [Regulatory Guide ], and in accordance with [Regulatory Guide 1.52, Revision 2, ASME N510-1989, and AG-1].

a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < [0.05]% when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below

[+/- 10%].

ESF Ventilation System Flowrate

[ ] [ ]

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < [0.05]% when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below [+/- 10%].

ESF Ventilation System Flowrate

[ ] [ ]

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in [Regulatory Guide 1.52, Revision 2], shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30°C (86°F) and the relative humidity specified below.

ESF Ventilation System Penetration RH Face Velocity (fps)

[ ] [See Reviewer's [See [See Reviewer's Note] Reviewer's Note]

Note]

REVIEWER'S NOTE----------------------------------------

The use of any standard other than ASTM D3803-1989 to test the charcoal sample may result in an overestimation of the capability of the charcoal to adsorb radioiodine. As a result, the ability of the charcoal filters to perform in a manner consistent with the licensing basis for the facility is indeterminate.

Westinghouse STS 5.5-10 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1011 Ventilation Filter Testing Program (continued)

ASTM D 3803-1989 is a more stringent testing standard because it does not differentiate between used and new charcoal, it has a longer equilibration period performed at a temperature of 30°C (86°F) and a relative humidity (RH) of 95%

(or 70% RH with humidity control), and it has more stringent tolerances that improve repeatability of the test.

Allowable Penetration = [(100% - Methyl Iodide Efficiency

for Charcoal Credited in Licensee's Accident Analysis) / Safety Factor]

When ASTM D3803-1989 is used with 30°C (86°F) and 95% RH (or 70% RH with humidity control) is used, the staff will accept the following:

Safety factor 2 for systems with or without humidity control.

Humidity control can be provided by heaters or an NRC-approved analysis that demonstrates that the air entering the charcoal will be maintained less than or equal to 70 percent RH under worst-case design-basis conditions.

If the system has a face velocity greater than 110 percent of 0.203 m/s (40 ft/min), the face velocity should be specified.

This value should be the efficiency that was incorporated in the licensee's accident analysis which was reviewed and approved by the staff in a safety evaluation.

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below [+/- 10%].

ESF Ventilation System Delta P Flowrate

[ ] [ ] [ ]

[ e. Demonstrate that the heaters for each of the ESF systems dissipate the value specified below [+/- 10%] when tested in accordance with

[ASME N510-1989].

ESF Ventilation System Wattage ]

[ ] [ ]

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

Westinghouse STS 5.5-11 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1112 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the [Waste Gas Holdup System], [the quantity of radioactivity contained in gas storage tanks or fed into the offgas treatment system, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks]. The gaseous radioactivity quantities shall be determined following the methodology in [Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure"]. The liquid radwaste quantities shall be determined in accordance with [Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures"].

The program shall include:

a. The limits for concentrations of hydrogen and oxygen in the [Waste Gas Holdup System] and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion),

b. A surveillance program to ensure that the quantity of radioactivity contained in [each gas storage tank and fed into the offgas treatment system] is less than the amount that would result in a whole body exposure of 0.5 rem to any individual in an unrestricted area, in the event of [an uncontrolled release of the tanks' contents], and

c. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the [Liquid Radwaste Treatment System] is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

Westinghouse STS 5.5-12 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1213 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1. An API gravity or an absolute specific gravity within limits,

2. A flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3. A clear and bright appearance with proper color or a water and sediment content within limits.

b. Within 31 days following addition of the new fuel oil to storage tanks, verify that the properties of the new fuel oil, other than those addressed in a.,

above, are within limits for ASTM 2D fuel oil, and

c. Total particulate concentration of the fuel oil is 10 mg/l when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test frequencies.

5.5.1314 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. A change in the TS incorporated in the license or

2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

Westinghouse STS 5.5-13 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1314 Technical Specifications (TS) Bases Control Program (continued)

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that meet the criteria of Specification 5.5.134.b above shall be reviewed and approved by the NRC prior to implementation.

Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.1415 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected,

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists,

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities, and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power, or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable, or

b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable, or Westinghouse STS 5.5-14 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1415 Safety Function Determination Program (SFDP) (continued)

c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.1516 Containment Leakage Rate Testing Program

[OPTION A]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option A, as modified by approved exemptions.

b. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]% of containment air weight per day.

c. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criterion is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and < 0.75 La for Type A tests.

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is [0.05 La] when tested at Pa.

b) For each door, leakage rate is [0.01 La] when pressurized to

[ 10 psig].

d. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

e. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

Westinghouse STS 5.5-15 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1516 Containment Leakage Rate Testing Program (continued)

[OPTION B]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September, 1995, as modified by the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

[ 3. ...]

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is [45 psig]. The containment design pressure is

[50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]% of containment air weight per day.

d. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criterion is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and 0.75 La for Type A tests.

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is [0.05 La] when tested at Pa.

b) For each door, leakage rate is [0.01 La] when pressurized to

[ 10 psig].

Westinghouse STS 5.5-16 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1516 Containment Leakage Rate Testing Program (continued)

e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

[OPTION A/B Combined]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J. [Type A][Type B and C] test requirements are in accordance with 10 CFR 50, Appendix J, Option A, as modified by approved exemptions. [Type B and C][Type A] test requirements are in accordance with 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. The 10 CFR 50, Appendix J, Option B test requirements shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September, 1995, as modified by the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

[ 3. ...]

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, [45 psig]. The containment design pressure is

[50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]% of containment air weight per day.

d. Leakage rate acceptance criteria are:

Westinghouse STS 5.5-17 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1516 Containment Leakage Rate Testing Program (continued)

1. Containment leakage rate acceptance criterion is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and [< 0.75 La for Option A Type A tests] [ 0.75 La for Option B Type A tests].

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is [0.05 La] when tested at Pa.

b) For each door, leakage rate is [0.01 La] when pressurized to

[ 10 psig].

e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

5.5.1617 Battery Monitoring and Maintenance Program

REVIEWERS NOTE------------------------------------------

This program and the corresponding requirements in LCO 3.8.4, LCO 3.8.5, and LCO 3.8.6 require providing the information and verifications requested in the Notice of Availability for TSTF-500, Revision 2, "DC Electrical Rewrite - Update to TSTF-360," (76FR54510).

This Program provides controls for battery restoration and maintenance. The program shall be in accordance with IEEE Standard (Std) 450-2002, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," as endorsed by Regulatory Guide 1.129, Revision 2 (RG), with RG exceptions and program provisions as identified below:

a. The program allows the following RG 1.129, Revision 2 exceptions:

1. Battery temperature correction may be performed before or after conducting discharge tests.

2. RG 1.129, Regulatory Position 1, Subsection 2, "References," is not applicable to this program.

Westinghouse STS 5.5-18 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1617 Battery Monitoring and Maintenance Program (continued)

3. In lieu of RG 1.129, Regulatory Position 2, Subsection 5.2, "Inspections," the following shall be used: "Where reference is made to the pilot cell, pilot cell selection shall be based on the lowest voltage cell in the battery."

4 In Regulatory Guide 1.129, Regulatory Position 3, Subsection 5.4.1, "State of Charge Indicator," the following statements in paragraph (d) may be omitted: "When it has been recorded that the charging current has stabilized at the charging voltage for three consecutive hourly measurements, the battery is near full charge. These measurements shall be made after the initially high charging current decreases sharply and the battery voltage rises to approach the charger output voltage."

5. In lieu of RG 1.129, Regulatory Position 7, Subsection 7.6, "Restoration," the following may be used: "Following the test, record the float voltage of each cell of the string."

b. The program shall include the following provisions:

1. Actions to restore battery cells with float voltage < [2.13] V;

2. Actions to determine whether the float voltage of the remaining battery cells is [2.13] V when the float voltage of a battery cell has been found to be < [2.13] V;

3. Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the plates;

4. Limits on average electrolyte temperature, battery connection resistance, and battery terminal voltage; and

5. A requirement to obtain specific gravity readings of all cells at each discharge test, consistent with manufacturer recommendations.

5.5.1718 Control Room Envelope (CRE) Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Filtration System (CREFS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of [5 rem whole body or its equivalent to any part of the body] [5 rem total Westinghouse STS 5.5-19 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1718 Control Room Envelope (CRE) Habitability Program (continued) effective dose equivalent (TEDE)] for the duration of the accident. The program shall include the following elements:

a. The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.

[The following are exceptions to Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0:

1. ;and]

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of [18] months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the

[18] month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

Westinghouse STS 5.5-20 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1819 [ Setpoint Control Program This program shall establish the requirements for ensuring that setpoints for automatic protective devices are initially within and remain within the assumptions of the applicable safety analyses, provides a means for processing changes to instrumentation setpoints, and identifies setpoint methodologies to ensure instrumentation will function as required. The program shall ensure that testing of automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1)(ii)(A) verifies that instrumentation will function as required.

a. The program shall list the Functions in the following specifications to which it applies:

1. LCO 3.3.1, "Reactor Trip System (RTS) Instrumentation;"

2. LCO 3.3.2, "Engineered Safety Feature Actuation System (ESFAS)

Instrumentation Functions;"

3. LCO 3.3.5, "Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation;"

4. LCO 3.3.6, "Containment Purge and Exhaust Isolation Instrumentation;"

5. LCO 3.3.7, "Control Room Emergency Filtration System (CREFS)

Actuation Instrumentation;"

6. LCO 3.3.8, "Fuel Building Air Cleanup System (FBACS) Actuation Instrumentation;" and

7. LCO 3.3.9, "Boron Dilution Protection System (BDPS)."

b. The program shall require the Nominal Trip Setpoint (NTSP), Allowable Value (AV), As-Found Tolerance (AFT), and As-Left Tolerance (ALT) (as applicable) of the Functions described in paragraph a. are calculated using the NRC approved setpoint methodology, as listed below. In addition, the program shall contain the value of the NTSP, AV, AFT, and ALT (as applicable) for each Function described in paragraph a. and shall identify the setpoint methodology used to calculate these values.

Reviewer's Note----------------------------------------

List the NRC safety evaluation report by letter, date, and ADAMS accession number (if available) that approved the setpoint methodologies.

1. [Insert reference to NRC safety evaluation that approved the setpoint methodology.]

c. The program shall establish methods to ensure that Functions described in paragraph a. will function as required by verifying the as-left and as-found settings are consistent with those established by the setpoint methodology.

Westinghouse STS 5.5-21 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1819 Setpoint Control Program (continued)

d. -----------------------------------REVIEWERS NOTE--------------------------------------

A license amendment request to implement a Setpoint Control Program must list the instrument functions to which the program requirements of paragraph d. will be applied. Paragraph d. shall apply to all Functions in the Reactor Trip System and Engineered Safety Feature Actuation System specifications unless one or more of the following exclusions apply:

1. Manual actuation circuits, automatic actuation logic circuits or to instrument functions that derive input from contacts which have no associated sensor or adjustable device, e.g., limit switches, breaker position switches, manual actuation switches, float switches, proximity detectors, etc. are excluded. In addition, those permissives and interlocks that derive input from a sensor or adjustable device that is tested as part of another TS function are excluded.

2. Settings associated with safety relief valves are excluded. The performance of these components is already controlled (i.e., trended with as-left and as-found limits) under the ASME Code for Operation and Maintenance of Nuclear Power Plants testing program.

3. Functions and Surveillance Requirements which test only digital components are normally excluded. There is no expected change in result between SR performances for these components. Where separate as-left and as-found tolerance is established for digital component SRs, the requirements would apply.

The program shall identify the Functions described in paragraph a. that are automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1)(ii)(A). The NTSP of these Functions are Limiting Safety System Settings. These Functions shall be demonstrated to be functioning as required by applying the following requirements during CHANNEL CALIBRATIONS, CHANNEL OPERATIONAL TESTS, and TRIP ACTUATING DEVICE OPERATIONAL TESTS that verify the NTSP.

1 The as-found value of the instrument channel trip setting shall be compared with the previous as-left value or the specified NTSP.

2. If the as-found value of the instrument channel trip setting differs from the previous as-left value or the specified NTSP by more than the pre-defined test acceptance criteria band (i.e., the specified AFT), then the instrument channel shall be evaluated before declaring the SR met and returning the instrument channel to service. This condition shall be entered in the plant corrective action program.

Westinghouse STS 5.5-22 Rev. 4.0

TSTF-545, Rev. 0 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1819 Setpoint Control Program (continued)

3. If the as-found value of the instrument channel trip setting is less conservative than the specified AV, then the SR is not met and the instrument channel shall be immediately declared inoperable.

4. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the NTSP at the completion of the surveillance test; otherwise, the channel is inoperable (setpoints may be more conservative than the NTSP provided that the as-found and as-left tolerances apply to the actual setpoint used to confirm channel performance).

e. The program shall be specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference]. ]

5.5.1920 [ Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.

b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program. ]

Westinghouse STS 5.5-23 Rev. 4.0

TSTF-545, Rev. 0 LCO Applicability B 3.0 BASES LCO 3.0.6 LCO 3.0.6 establishes an exception to LCO 3.0.2 for supported systems that have a support system LCO specified in the Technical Specifications (TS). This exception is provided because LCO 3.0.2 would require that the Conditions and Required Actions of the associated inoperable supported system LCO be entered solely due to the inoperability of the support system. This exception is justified because the actions that are required to ensure the unit is maintained in a safe condition are specified in the support system LCO's Required Actions. These Required Actions may include entering the supported system's Conditions and Required Actions or may specify other Required Actions.

When a support system is inoperable and there is an LCO specified for it in the TS, the supported system(s) are required to be declared inoperable if determined to be inoperable as a result of the support system inoperability. However, it is not necessary to enter into the supported systems' Conditions and Required Actions unless directed to do so by the support system's Required Actions. The potential confusion and inconsistency of requirements related to the entry into multiple support and supported systems' LCOs' Conditions and Required Actions are eliminated by providing all the actions that are necessary to ensure the unit is maintained in a safe condition in the support system's Required Actions.

However, there are instances where a support system's Required Action may either direct a supported system to be declared inoperable or direct entry into Conditions and Required Actions for the supported system.

This may occur immediately or after some specified delay to perform some other Required Action. Regardless of whether it is immediate or after some delay, when a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

Specification 5.5.1415, "Safety Function Determination Program (SFDP),"

ensures loss of safety function is detected and appropriate actions are taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other limitations, remedial actions, or compensatory actions may be identified as a result of the support system inoperability and corresponding exception to entering supported system Conditions and Required Actions. The SFDP implements the requirements of LCO 3.0.6.

Westinghouse STS B 3.0-8 Rev. 4.0

TSTF-545, Rev. 0 SR Applicability B 3.0 BASES SR 3.0.2 (continued) 25% extension of the interval specified in the Frequency does not apply.

These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. An Eexamples of where SR 3.0.2 does not apply areis in the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the American Society of Mechanical Engineers (ASME) Code inservice testing required by 10 CFR 50.55a. Theseis programs establishes testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a test interval specified in the regulations directly or by reference.

As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "once per ..." basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable equipment in an alternative manner.

The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified.

SR 3.0.3 SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been performed in accordance with SR 3.0.2, and not at the time that the specified Frequency was not met.

This delay period provides adequate time to complete Surveillances that have been missed. This delay period permits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance.

The basis for this delay period includes consideration of unit conditions, adequate planning, availability of personnel, the time required to perform the Surveillance, the safety significance of the delay in completing the required Surveillance, and the recognition that the most probable result of Westinghouse STS B 3.0-18 Rev. 4.0

TSTF-545, Rev. 0 Pressurizer Safety Valves B 3.4.10 BASES SURVEILLANCE SR 3.4.10.1 REQUIREMENTS SRs are specified in the INSERVICE TESTING PROGRAM Inservice Testing Program. Pressurizer safety valves are to be tested in accordance with the requirements of the ASME Code (Ref. 4), which provides the activities and Frequencies necessary to satisfy the SRs. No additional requirements are specified.

The pressurizer safety valve setpoint is +/- [3]% for OPERABILITY; however, the valves are reset to +/- 1% during the Surveillance to allow for drift.

REFERENCES 1. ASME, Boiler and Pressure Vessel Code, Section III.

2. FSAR, Chapter [15].

3. WCAP-7769, Rev. 1, June 1972.

4. ASME Code for Operation and Maintenance of Nuclear Power Plants.

Westinghouse STS B 3.4.10-4 Rev. 4.0

TSTF-545, Rev. 0 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)

The [HPI] pump[s] and charging pump[s] are rendered incapable of injecting into the RCS through removing the power from the pumps by racking the breakers out under administrative control. An alternate method of LTOP control may be employed using at least two independent means to prevent a pump start such that a single failure or single action will not result in an injection into the RCS. This may be accomplished through the pump control switch being placed in [pull to lock] and at least one valve in the discharge flow path being closed.

[ The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering other indications and alarms available to the operator in the control room, to verify the required status of the equipment.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

[ SR 3.4.12.4 Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RHR suction valve and RHR suction isolation valves are open and by testing it in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. (Refer to SR 3.4.12.7 for the RHR suction isolation valve Surveillance.) This Surveillance is only required to be performed if the RHR suction relief valve is being used to meet this LCO.

The RHR suction valve is verified to be opened. [ The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is considered adequate in view of other administrative controls such as valve status indications available to the operator in the control room that verify the RHR suction valve remains open.

OR Westinghouse STS B 3.4.12-11 Rev. 4.0

TSTF-545, Rev. 0 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

The ASME Code (Ref. 8), test per INSERVICE TESTING PROGRAM Inservice Testing Program verifies OPERABILITY by proving proper relief valve mechanical motion and by measuring and, if required, adjusting the lift setpoint. ]

SR 3.4.12.5 The RCS vent of [2.07] square inches is proven OPERABLE by verifying its open condition [ either:

a. Once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for a valve that is not locked (valves that are sealed or secured in the open position are considered "locked" in this context) or

b. Once every 31 days for other vent path(s) (e.g., a vent valve that is locked, sealed, or secured in position). A removed pressurizer safety valve or open manway also fits this category.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

Westinghouse STS B 3.4.12-12 Rev. 4.0

TSTF-545, Rev. 0 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)

The passive vent path arrangement must only be open to be OPERABLE.

This Surveillance is required to be met if the vent is being used to satisfy the pressure relief requirements of the LCO 3.4.12d.

SR 3.4.12.6 The PORV block valve must be verified open to provide the flow path for each required PORV to perform its function when actuated. The valve must be remotely verified open in the main control room. [This Surveillance is performed if the PORV satisfies the LCO.]

The block valve is a remotely controlled, motor operated valve. The power to the valve operator is not required removed, and the manual operator is not required locked in the inactive position. Thus, the block valve can be closed in the event the PORV develops excessive leakage or does not close (sticks open) after relieving an overpressure situation.

[ The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Frequency is considered adequate in view of other administrative controls available to the operator in the control room, such as valve position indication, that verify that the PORV block valve remains open.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

[ SR 3.4.12.7 Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RHR suction valve and RHR suction isolation valve are open and by testing it in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. (Refer to SR 3.4.12.4 for the RHR suction valve Surveillance and for a description of the requirements of the INSERVICE TESTING PROGRAM Inservice Testing Program.) This Surveillance is only performed if the RHR suction relief valve is being used to satisfy this LCO. ]

Westinghouse STS B 3.4.12-13 Rev. 4.0

TSTF-545, Rev. 0 RCS PIV Leakage B 3.4.14 BASES SURVEILLANCE SR 3.4.14.1 REQUIREMENTS Performance of leakage testing on each RCS PIV or isolation valve used to satisfy Required Action A.1 and Required Action A.2 is required to verify that leakage is below the specified limit and to identify each leaking valve. The leakage limit of 0.5 gpm per inch of nominal valve diameter up to 5 gpm maximum applies to each valve. Leakage testing requires a stable pressure condition.

For the two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves. If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement. In this situation, the protection provided by redundant valves would be lost.

Testing is to be performed every [9] months, but may be extended, if the plant does not go into MODE 5 for at least 7 days. [ The [18 month]

Frequency is consistent with 10 CFR 50.55a(g) (Ref. 8) and the INSERVICE TESTING PROGRAM as contained in the Inservice Testing Program, is within frequency allowed by the American Society of Mechanical Engineers (ASME) Code (Ref. 7), and is based on the need to perform such surveillances under the conditions that apply during an outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

In addition, testing must be performed once after the valve has been opened by flow or exercised to ensure tight reseating. PIVs disturbed in the performance of this Surveillance should also be tested unless documentation shows that an infinite testing loop cannot practically be avoided. Testing must be performed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after the valve has been reseated. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is a reasonable and practical time limit for performing this test after opening or reseating a valve.

Westinghouse STS B 3.4.14-5 Rev. 4.0

TSTF-545, Rev. 0 SG Tube Integrity B 3.4.20 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.20 Steam Generator (SG) Tube Integrity BASES BACKGROUND Steam generator (SG) tubes are small diameter, thin walled tubes that carry primary coolant through the primary to secondary heat exchangers.

The SG tubes have a number of important safety functions. Steam generator tubes are an integral part of the reactor coolant pressure boundary (RCPB) and, as such, are relied on to maintain the primary systems pressure and inventory. The SG tubes isolate the radioactive fission products in the primary coolant from the secondary system. In addition, as part of the RCPB, the SG tubes are unique in that they act as the heat transfer surface between the primary and secondary systems to remove heat from the primary system. This Specification addresses only the RCPB integrity function of the SG. The SG heat removal function is addressed by LCO 3.4.4, "RCS Loops - MODES 1 and 2," LCO 3.4.5, "RCS Loops - MODE 3," LCO 3.4.6, "RCS Loops - MODE 4," and LCO 3.4.7, "RCS Loops - MODE 5, Loops Filled."

SG tube integrity means that the tubes are capable of performing their intended RCPB safety function consistent with the licensing basis, including applicable regulatory requirements.

Steam generator tubing is subject to a variety of degradation mechanisms. Steam generator tubes may experience tube degradation related to corrosion phenomena, such as wastage, pitting, intergranular attack, and stress corrosion cracking, along with other mechanically induced phenomena such as denting and wear. These degradation mechanisms can impair tube integrity if they are not managed effectively.

The SG performance criteria are used to manage SG tube degradation.

Specification 5.5.89, "Steam Generator (SG) Program," requires that a program be established and implemented to ensure that SG tube integrity is maintained. Pursuant to Specification 5.5.89, tube integrity is maintained when the SG performance criteria are met. There are three SG performance criteria: structural integrity, accident induced leakage, and operational LEAKAGE. The SG performance criteria are described in Specification 5.5.89. Meeting the SG performance criteria provides reasonable assurance of maintaining tube integrity at normal and accident conditions.

The processes used to meet the SG performance criteria are defined by the Steam Generator Program Guidelines (Ref. 1).

Westinghouse STS B 3.4.20-1 Rev. 4.0

TSTF-545, Rev. 0 SG Tube Integrity B 3.4.20 BASES APPLICABLE The steam generator tube rupture (SGTR) accident is the limiting design SAFETY basis event for SG tubes and avoiding an SGTR is the basis for this ANALYSES Specification. The analysis of a SGTR event assumes a bounding primary to secondary LEAKAGE rate equal to the operational LEAKAGE rate limits in LCO 3.4.13, "RCS Operational LEAKAGE," plus the leakage rate associated with a double-ended rupture of a single tube. The accident analysis for a SGTR assumes the contaminated secondary fluid is only briefly released to the atmosphere via safety valves and the majority is discharged to the main condenser.

The analysis for design basis accidents and transients other than a SGTR assume the SG tubes retain their structural integrity (i.e., they are assumed not to rupture.) In these analyses, the steam discharge to the atmosphere is based on the total primary to secondary LEAKAGE from all SGs of [1 gallon per minute] or is assumed to increase to [1 gallon per minute] as a result of accident induced conditions. For accidents that do not involve fuel damage, the primary coolant activity level of DOSE EQUIVALENT I-131 is assumed to be equal to the LCO 3.4.16, "RCS Specific Activity," limits. For accidents that assume fuel damage, the primary coolant activity is a function of the amount of activity released from the damaged fuel. The dose consequences of these events are within the limits of GDC 19 (Ref. 2), 10 CFR 100 (Ref. 3) or the NRC approved licensing basis (e.g., a small fraction of these limits).

Steam generator tube integrity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).

LCO The LCO requires that SG tube integrity be maintained. The LCO also requires that all SG tubes that satisfy the repair criteria be plugged [or repaired] in accordance with the Steam Generator Program.

During an SG inspection, any inspected tube that satisfies the Steam Generator Program repair criteria is [repaired or] removed from service by plugging. If a tube was determined to satisfy the repair criteria but was not plugged [or repaired], the tube may still have tube integrity.

In the context of this Specification, a SG tube is defined as the entire length of the tube, including the tube wall [and any repairs made to it],

between the tube-to-tubesheet weld at the tube inlet and the tube-to-tubesheet weld at the tube outlet. The tube-to-tubesheet weld is not considered part of the tube.

A SG tube has tube integrity when it satisfies the SG performance criteria.

The SG performance criteria are defined in Specification 5.5.89, "Steam Generator Program," and describe acceptable SG tube performance.

The Steam Generator Program also provides the evaluation process for determining conformance with the SG performance criteria.

Westinghouse STS B 3.4.20-2 Rev. 4.0

TSTF-545, Rev. 0 SG Tube Integrity B 3.4.20 BASES SURVEILLANCE REQUIREMENTS (continued)

The Steam Generator Program determines the scope of the inspection and the methods used to determine whether the tubes contain flaws satisfying the tube repair criteria. Inspection scope (i.e., which tubes or areas of tubing within the SG are to be inspected) is a function of existing and potential degradation locations. The Steam Generator Program also specifies the inspection methods to be used to find potential degradation.

Inspection methods are a function of degradation morphology, non-destructive examination (NDE) technique capabilities, and inspection locations.

The Steam Generator Program defines the Frequency of SR 3.4.20.1.

The Frequency is determined by the operational assessment and other limits in the SG examination guidelines (Ref. 6). The Steam Generator Program uses information on existing degradations and growth rates to determine an inspection Frequency that provides reasonable assurance that the tubing will meet the SG performance criteria at the next scheduled inspection. In addition, Specification 5.5.89 contains prescriptive requirements concerning inspection intervals to provide added assurance that the SG performance criteria will be met between scheduled inspections.

SR 3.4.20.2 During an SG inspection, any inspected tube that satisfies the Steam Generator Program repair criteria is [repaired or] removed from service by plugging. The tube repair criteria delineated in Specification 5.5.89 are intended to ensure that tubes accepted for continued service satisfy the SG performance criteria with allowance for error in the flaw size measurement and for future flaw growth. In addition, the tube repair criteria, in conjunction with other elements of the Steam Generator Program, ensure that the SG performance criteria will continue to be met until the next inspection of the subject tube(s). Reference 1 provides guidance for performing operational assessments to verify that the tubes remaining in service will continue to meet the SG performance criteria.

[Steam generator tube repairs are only performed using approved repair methods as described in the Steam Generator Program.]

The Frequency of prior to entering MODE 4 following a SG inspection ensures that the Surveillance has been completed and all tubes meeting the repair criteria are plugged [or repaired] prior to subjecting the SG tubes to significant primary to secondary pressure differential.

Westinghouse STS B 3.4.20-6 Rev. 4.0

TSTF-545, Rev. 0 ECCS - Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.3 With the exception of the operating centrifugal charging pump, the ECCS pumps are normally in a standby, nonoperating mode. As such, flow path piping has the potential to develop voids and pockets of entrained gases.

Maintaining the piping from the ECCS pumps to the RCS full of water ensures that the system will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent water hammer, pump cavitation, and pumping of noncondensible gas (e.g., air, nitrogen, or hydrogen) into the reactor vessel following an SI signal or during shutdown cooling. [ The 31 day Frequency takes into consideration the gradual nature of gas accumulation in the ECCS piping and the procedural controls governing system operation.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.5.2.4 Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME Code. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the plant safety analysis.

SRs are specified in the INSERVICE TESTING PROGRAM Inservice Testing Program of the ASME Code. The ASME Code provides the activities and Frequencies necessary to satisfy the requirements.

Westinghouse STS B 3.5.2-9 Rev. 4.0

TSTF-545, Rev. 0 ECCS - Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.5 and SR 3.5.2.6 These Surveillances demonstrate that each automatic ECCS valve actuates to the required position on an actual or simulated SI signal and that each ECCS pump starts on receipt of an actual or simulated SI signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. [ The 18 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for unplanned plant transients if the Surveillances were performed with the reactor at power. The 18 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment. The actuation logic is tested as part of ESF Actuation System testing, and equipment performance is monitored as part of the INSERVICE TESTING PROGRAM Inservice Testing Program.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.5.2.7 Realignment of valves in the flow path on an SI signal is necessary for proper ECCS performance. These valves have stops to allow proper positioning for restricted flow to a ruptured cold leg, ensuring that the other cold legs receive at least the required minimum flow. This Surveillance is not required for plants with flow limiting orifices. [ The 18 month Frequency is based on the same reasons as those stated in SR 3.5.2.5 and SR 3.5.2.6.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

Westinghouse STS B 3.5.2-10 Rev. 4.0

TSTF-545, Rev. 0 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)

B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued)

This Note allows valves and blind flanges located in high radiation areas to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, and 4, for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in their proper position, is small.

SR 3.6.3.5 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses.

REVIEWERS NOTE-----------------------------------

If the testing is within the scope of the licensee's INSERVICE TESTING PROGRAM Inservice Testing Program, the Frequency "In accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program" should be used. Otherwise, the periodic Frequency of 92 days or the reference to the Surveillance Frequency Control Program should be used.

[ The [isolation time and] Frequency of this SR is in accordance with [the INSERVICE TESTING PROGRAM Inservice Testing Program] [92 days.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.] ]

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

[ SR 3.6.3.6 In subatmospheric containments, the check valves that serve a containment isolation function are weight or spring loaded to provide positive closure in the direction of flow. This ensures that these check valves will remain closed when the inside containment atmosphere Westinghouse STS B 3.6.3-16 Rev. 4.0

TSTF-545, Rev. 0 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)

B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) returns to subatmospheric conditions following a DBA. SR 3.6.3.6 requires verification of the operation of the check valves that are testable during unit operation. [ The Frequency of 92 days is consistent with the INSERVICE TESTING PROGRAM Inservice Testing Program requirement for valve testing on a 92 day Frequency.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

] ]

[ SR 3.6.3.7 For containment purge valves with resilient seals, additional leakage rate testing beyond the test requirements of 10 CFR 50, Appendix J, Option

[A][B], is required to ensure OPERABILITY. Operating experience has demonstrated that this type of seal has the potential to degrade in a shorter time period than do other seal types. [ Based on this observation and the importance of maintaining this penetration leak tight (due to the direct path between containment and the environment), a Frequency of 184 days was established as part of the NRC resolution of Generic Issue B-20, "Containment Leakage Due to Seal Deterioration" (Ref. 5).

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

Additionally, this SR must be performed within 92 days after opening the valve. The 92 day Frequency was chosen recognizing that cycling the Westinghouse STS B 3.6.3-17 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems (Atmospheric and Dual)

B 3.6.6A BASES SURVEILLANCE REQUIREMENTS (continued)

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6A.4 Verifying each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref. 8). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by abnormal performance. The Frequency of the SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.6.6A.5 and SR 3.6.6A.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated actuation of a containment High-3 pressure signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. [ The [18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power.

Operating experience has shown that these components usually pass the Surveillances when performed at the [18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

Westinghouse STS B 3.6.6A-9 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems (Atmospheric and Dual)

B 3.6.6B BASES SURVEILLANCE REQUIREMENTS (continued)

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6B.3 Verifying that each [required] containment cooling train ESW cooling flow rate to each cooling unit is [700] gpm provides assurance that the design flow rate assumed in the analyses will be achieved (Ref. 3). [ The Frequency of 31 days was developed considering the known reliability of the Cooling Water System, the two train redundancy available, and the low probability of a significant degradation of flow occurring between surveillances.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6B.4 Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref. 8). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice Westinghouse STS B 3.6.6B-8 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray and Cooling Systems (Atmospheric and Dual)

B 3.6.6B BASES SURVEILLANCE REQUIREMENTS (continued) inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.6.6B.5 and SR 3.6.6B.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated containment High-3 pressure signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. [ The [18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillances when performed at the [18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

The surveillance of containment sump isolation valves is also required by SR 3.5.2.5. A single surveillance may be used to satisfy both requirements.

Westinghouse STS B 3.6.6B-9 Rev. 4.0

TSTF-545, Rev. 0 Containment Spray System (Ice Condenser)

B 3.6.6C BASES SURVEILLANCE REQUIREMENTS (continued)

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6.2 Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref. 5). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.6.6.3 and SR 3.6.6.4 These SRs require verification that each automatic containment spray valve actuates to its correct position and each containment spray pump starts upon receipt of an actual or simulated containment spray actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. [ The [18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillances when performed at the

[18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

OR Westinghouse STS B 3.6.6C-6 Rev. 4.0

TSTF-545, Rev. 0 QS System (Subatmospheric)

B 3.6.6D BASES SURVEILLANCE REQUIREMENTS (continued)

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6D.2 Verifying that each QS pump's developed head at the flow test point is greater than or equal to the required developed head ensures that QS pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref. 4). Since the QS System pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.6.6D.3 and SR 3.6.6D.4 These SRs ensure that each QS automatic valve actuates to its correct position and each QS pump starts upon receipt of an actual or simulated containment spray actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. [ The [18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power.

Operating experience has shown that these components usually pass the Surveillances when performed at an [18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

Westinghouse STS B 3.6.6D-5 Rev. 4.0

TSTF-545, Rev. 0 RS System (Subatmospheric)

B 3.6.6E BASES SURVEILLANCE REQUIREMENTS (continued)

[ The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.6E.5 Verifying that each RS [and casing cooling] pump's developed head at the flow test point is greater than or equal to the required developed head ensures that these pumps' performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref. 4). Since the QS System pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.6.6E.6 These SRs ensure that each automatic valve actuates and that the RS System and casing cooling pumps start upon receipt of an actual or simulated High-High containment pressure signal. Start delay times are also verified for the RS System pumps. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. [ The [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating Westinghouse STS B 3.6.6E-8 Rev. 4.0

TSTF-545, Rev. 0 HMS (Atmospheric, Ice Condenser, and Dual)

B 3.6.9 BASES ACTIONS (continued)

REVIEWERS NOTE-----------------------------------

The following is to be used if a non-Technical Specification alternate hydrogen control function is used to justify this Condition: In addition, the alternate hydrogen control system capability must be verified once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter to ensure its continued availability.

[Both] the [initial] verification [and all subsequent verifications] may be performed as an administrative check, by examining logs or other information to determine the availability of the alternate hydrogen control system. It does not mean to perform the Surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control system. If the ability to perform the hydrogen control function is maintained, continued operation is permitted with two HMS trains inoperable for up to 7 days. Seven days is a reasonable time to allow two HMS trains to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of a LOCA that would generate hydrogen in the amounts capable of exceeding the flammability limit.

C.1 If an inoperable HMS train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . The allowed Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.6.9.1 REQUIREMENTS Operating each HMS train for 15 minutes ensures that each train is OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan and/or motor failure, or excessive vibration can be detected for corrective action. [ The 92 day Frequency is consistent with INSERVICE TESTING PROGRAM Inservice Testing Program Surveillance Frequencies, operating experience, the known reliability of the fan motors and controls, and the two train redundancy available.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

Westinghouse STS B 3.6.9-4 Rev. 4.0

TSTF-545, Rev. 0 HMS (Atmospheric, Ice Condenser, and Dual)

B 3.6.9 BASES SURVEILLANCE REQUIREMENTS (continued)

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.9.2 Verifying that each HMS train flow rate on slow speed is [4000] cfm ensures that each train is capable of maintaining localized hydrogen concentrations below the flammability limit. [ The [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually pass the Surveillance when performed at the [18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.6.9.3 This SR ensures that each HMS train responds properly to a containment cooling actuation signal. The Surveillance verifies that each fan starts on slow speed from the nonoperating condition and that each fan shifts to slow speed from fast operating condition. [ The [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if Westinghouse STS B 3.6.9-5 Rev. 4.0

TSTF-545, Rev. 0 Vacuum Relief Valves (Atmospheric and Ice Condenser)

B 3.6.12 BASES SURVEILLANCE SR 3.6.12.1 REQUIREMENTS This SR cites the INSERVICE TESTING PROGRAM Inservice Testing Program, which establishes the requirement that inservice testing of the ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with the ASME Code (Ref. 2). Therefore, SR Frequency is governed by the INSERVICE TESTING PROGRAM Inservice Testing Program.

REFERENCES 1. FSAR, Section [6.2].

2. ASME Code for Operation and Maintenance of Nuclear Power Plants.

Westinghouse STS B 3.6.12-3 Rev. 4.0

TSTF-545, Rev. 0 MSSVs B 3.7.1 BASES APPLICABLE SAFETY ANALYSES (continued) an RCS heatup event (e.g., turbine trip). Thus, for any number of inoperable MSSVs, it is necessary to reduce the trip setpoint if a positive MTC may exist at partial power conditions, unless it is demonstrated by analysis that a specified reactor power reduction alone is sufficient to prevent overpressurization of the steam system.]

The MSSVs are assumed to have two active and one passive failure modes. The active failure modes are spurious opening, and failure to reclose once opened. The passive failure mode is failure to open upon demand.

The MSSVs satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).

LCO The accident analysis requires that [five] MSSVs per steam generator be OPERABLE to provide overpressure protection for design basis transients occurring at 102% RTP. The LCO requires that [five] MSSVs per steam generator be OPERABLE in compliance with Reference 2, and the DBA analysis.

The OPERABILITY of the MSSVs is defined as the ability to open upon demand within the setpoint tolerances, to relieve steam generator overpressure, and reseat when pressure has been reduced. The OPERABILITY of the MSSVs is determined by periodic surveillance testing in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

This LCO provides assurance that the MSSVs will perform their designed safety functions to mitigate the consequences of accidents that could result in a challenge to the RCPB, or Main Steam System integrity.

APPLICABILITY In MODES 1, 2, and 3, [five] MSSVs per steam generator are required to be OPERABLE to prevent Main Steam System overpressurization.

In MODES 4 and 5, there are no credible transients requiring the MSSVs.

The steam generators are not normally used for heat removal in MODES 5 and 6, and thus cannot be overpressurized; there is no requirement for the MSSVs to be OPERABLE in these MODES.

Westinghouse STS B 3.7.1-3 Rev. 4.0

TSTF-545, Rev. 0 MSSVs B 3.7.1 BASES ACTIONS (continued)

The maximum THERMAL POWER corresponding to the heat removal capacity of the remaining OPERABLE MSSVs is determined via a conservative heat balance calculation as described in the attachment to Reference 6, with an appropriate allowance for Nuclear Instrumentation System trip channel uncertainties.

REVIEWERS NOTE-----------------------------------

To determine the Table 3.7.1-1 Maximum Allowable Power for Required Actions B.1 and B.2 (%RTP), the Maximum NSSS Power calculated using the equation in the Reviewer's Note above is reduced by [9]% RTP to account for Nuclear Instrumentation System trip channel uncertainties.

Required Action B.2 is modified by a Note, indicating that the Power Range Neutron Flux-High reactor trip setpoint reduction is only required in MODE 1. In MODES 2 and 3 the reactor protection system trips specified in LCO 3.3.1, "Reactor Trip System Instrumentation," provide sufficient protection.

The allowed Completion Times are reasonable based on operating experience to accomplish the Required Actions in an orderly manner without challenging unit systems.

C.1 and C.2 If the Required Actions are not completed within the associated Completion Time, or if one or more steam generators have [4]

inoperable MSSVs, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

SURVEILLANCE SR 3.7.1.1 REQUIREMENTS This SR verifies the OPERABILITY of the MSSVs by the verification of each MSSV lift setpoint in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. The ASME Code (Ref. 4),

requires that safety and relief valve tests be performed in accordance with ANSI/ASME OM-1-1987 (Ref. 5). According to Reference 5, the following tests are required:

a. Visual examination, Westinghouse STS B 3.7.1-6 Rev. 4.0

TSTF-545, Rev. 0 MSIVs B 3.7.2 BASES ACTIONS (continued)

C.1 and C.2 Condition C is modified by a Note indicating that separate Condition entry is allowed for each MSIV.

Since the MSIVs are required to be OPERABLE in MODES 2 and 3, the inoperable MSIVs may either be restored to OPERABLE status or closed.

When closed, the MSIVs are already in the position required by the assumptions in the safety analysis.

The [8] hour Completion Time is consistent with that allowed in Condition A.

For inoperable MSIVs that cannot be restored to OPERABLE status within the specified Completion Time, but are closed, the inoperable MSIVs must be verified on a periodic basis to be closed. This is necessary to ensure that the assumptions in the safety analysis remain valid. The 7 day Completion Time is reasonable, based on engineering judgment, in view of MSIV status indications available in the control room, and other administrative controls, to ensure that these valves are in the closed position.

D.1 and D.2 If the MSIVs cannot be restored to OPERABLE status or are not closed within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed at least in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from MODE 2 conditions in an orderly manner and without challenging unit systems.

SURVEILLANCE SR 3.7.2.1 REQUIREMENTS This SR verifies that the closure time of each MSIV is within the limit given in Reference 5 and is within that assumed in the accident and containment analyses. This SR also verifies the valve closure time is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. This SR is normally performed upon returning the unit to operation following a refueling outage. The MSIVs should not be tested at power, since even a part stroke exercise increases the risk of a valve closure when the unit is generating power. As the MSIVs are not tested at power, they are exempt from the ASME Code (Ref. 6), requirements during operation in MODE 1 or 2.

Westinghouse STS B 3.7.2-4 Rev. 4.0

TSTF-545, Rev. 0 MSIVs B 3.7.2 BASES SURVEILLANCE REQUIREMENTS (continued)

The Frequency is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

This test is conducted in MODE 3 with the unit at operating temperature and pressure. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. This allows a delay of testing until MODE 3, to establish conditions consistent with those under which the acceptance criterion was generated.

SR 3.7.2.2 This SR verifies that each MSIV can close on an actual or simulated actuation signal. This Surveillance is normally performed upon returning the plant to operation following a refueling outage. [ The Frequency of MSIV testing is every [18] months. The [18] month Frequency for testing is based on the refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the

[18] month Frequency. Therefore, this Frequency is acceptable from a reliability standpoint.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

REFERENCES 1. FSAR, Section [10.3].

2. FSAR, Section [6.2].

3. FSAR, Section [15.1.5].

4. 10 CFR 100.11.

5. [Technical Requirements Manual.]

6. ASME Code for Operation and Maintenance of Nuclear Power Plants.

Westinghouse STS B 3.7.2-5 Rev. 4.0

TSTF-545, Rev. 0 MFIVs and MFRVs [and Associated Bypass Valves]

B 3.7.3 BASES ACTIONS (continued)

E.1 and E.2 If the MFIV(s) and MFRV(s) and the associated bypass valve(s) cannot be restored to OPERABLE status, or closed, or isolated within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months [, and in MODE 4 within 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s]. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

SURVEILLANCE SR 3.7.3.1 REQUIREMENTS This SR verifies that the closure time of each MFIV, MFRV, and

[associated bypass valve] is within the limit given in Reference 2 and is within that assumed in the accident and containment analyses. This SR also verifies the valve closure time is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program. This SR is normally performed upon returning the unit to operation following a refueling outage. These valves should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the ASME Code (Ref. 3),

quarterly stroke requirements during operation in MODES 1 and 2.

The Frequency for this SR is in accordance with the INSERVICE TESTING PROGRAM Inservice Testing Program.

SR 3.7.3.2 This SR verifies that each MFIV, MFRV, and [associated bypass valves]

can close on an actual or simulated actuation signal. This Surveillance is normally performed upon returning the plant to operation following a refueling outage.

[ The Frequency for this SR is every [18] months. The [18] month Frequency for testing is based on the refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the [18] month Frequency. Therefore, this Frequency is acceptable from a reliability standpoint.

OR Westinghouse STS B 3.7.3-5 Rev. 4.0

TSTF-545, Rev. 0 AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued) used during startup, shutdown, hot standby operations, and hot shutdown operations for steam generator level control, and these manual operations are an accepted function of the AFW System, OPERABILITY (i.e., the intended safety function) continues to be maintained. ]

[ The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.

OR The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

REVIEWERS NOTE-----------------------------------

Plants controlling Surveillance Frequencies under a Surveillance Frequency Control Program should utilize the appropriate Frequency description, given above, and the appropriate choice of Frequency in the Surveillance Requirement.

]

SR 3.7.5.2 Verifying that each AFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that AFW pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref 2). Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing is performed on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance.

Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. Performance of inservice testing as discussed in the ASME Code (Ref. 2) and the INSERVICE TESTING PROGRAM (only required at 3 month intervals) satisfies this requirement.

[ This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions are established. This deferral is required because there is insufficient steam pressure to perform the test. ]

Westinghouse STS B 3.7.5-8 Rev. 4.0

TSTF-545, Rev. 0 Battery Parameters B 3.8.6 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.6 Battery Parameters BASES BACKGROUND This LCO delineates the limits on battery float current as well as electrolyte temperature, level, and float voltage for the DC power subsystem batteries. A discussion of these batteries and their OPERABILITY requirements is provided in the Bases for LCO 3.8.4, "DC Sources - Operating," and LCO 3.8.5, "DC Sources - Shutdown." In addition to the limitations of this Specification, the [licensee controlled program] also implements a program specified in Specification 5.5.1617 for monitoring various battery parameters.

The battery cells are of flooded lead acid construction with a nominal specific gravity of [1.215]. This specific gravity corresponds to an open circuit battery voltage of approximately 120 V for [58] cell battery (i.e., cell voltage of [2.065] volts per cell (Vpc)). The open circuit voltage is the voltage maintained when there is no charging or discharging. Once fully charged with its open circuit voltage [2.065] Vpc, the battery cell will maintain its capacity for [30] days without further charging per manufacturer's instructions. Optimal long term performance however, is obtained by maintaining a float voltage [2.20 to 2.25] Vpc. This provides adequate over-potential which limits the formation of lead sulfate and self discharge. The nominal float voltage of [2.22] Vpc corresponds to a total float voltage output of [128.8] V for a [58] cell battery as discussed in the FSAR, Chapter [8] (Ref. 2).

APPLICABLE The initial conditions of Design Basis Accident (DBA) and transient SAFETY analyses in the FSAR, Chapter [6] (Ref. 3) and Chapter [15] (Ref. 4),

ANALYSES assume Engineered Safety Feature systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the DGs, emergency auxiliaries, and control and switching during all MODES of operation.

The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the unit. This includes maintaining at least one subsystem of DC sources OPERABLE during accident conditions, in the event of:

a. An assumed loss of all offsite AC power or all onsite AC power and

b. A worst-case single failure.

Battery parameters satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).

Westinghouse STS B 3.8.6-1 Rev. 4.0