LR-N06-0201, Request for Change to Technical Specifications to Eliminate Requirements for Hydrogen Recombiners and Hydrogen Analyzers Using the Consolidated Line Item Improvement Process

Request for Change to Technical Specifications to Eliminate Requirements for Hydrogen Recombiners and Hydrogen Analyzers Using the Consolidated Line Item Improvement Process

ML061660145
Person / Time
Site:	Salem
Issue date:	06/07/2006
From:	Joyce T Public Service Enterprise Group
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
LCR S06-05, LR-N06-0201
Download: ML061660145 (24)

Text

PSEG Nuclear LLC P.O. Box 236, Hancocks Bridge, New Jersey 08038-0236

!JUN 0 7 2006 0 PSEG Nuclear LLC LR-N06-0201 LCR S06-05 United States Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 REQUEST FOR CHANGE TO TECHNICAL SPECIFICATIONS TO ELIMINATE REQUIREMENTS FOR HYDROGEN RECOMBINERS AND HYDROGEN ANALYZERS USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS SALEM GENERATING STATION - UNIT I AND UNIT 2 DOCKET NO. 50-272 AND 50-311 FACILITY OPERATING LICENSE NO. DPR-70 AND DPR-75 In accordance with the provisions of 10 CFR 50.90, PSEG Nuclear, LLC (PSEG) hereby transmits a request for amendment of the Technical Specifications (TS) for Salem Generating Station Unit 1 and Unit 2.

The proposed amendment will delete the TS requirements related to hydrogen recombiners and hydrogen analyzers. The proposed TS changes support implementation of the revisions to 10 CFR 50.44, "Standards for Combustible Gas Control System in Light-Water-Cooled Power Reactors," that became effective on October 16, 2003. The changes are consistent with Revision 1 of NRC-approved Industry/Technical Specification Task Force (TSTF) Standard Technical Specification (STS) Change Traveler, TSTF-447, "Elimination of Hydrogen Recombiners and Change to Hydrogen and Oxygen Monitors." The availability of this TS improvement was announced in the FederalRegisteron September 25, 2003, as part of the Consolidated Line Item Improvement Process (CLIIP).

Attachment I provides a description of the proposed change, the requested confirmation of applicability and plant-specific verifications. Attachment 2 provides the existing TS pages marked up to show the proposed changes. summarizes the regulatory commitments made in this submittal and Attachment 4 provides the existing TS Bases pages marked up to show the proposed changes.

0ooI 95-2168 REV. 7/99

d Document Control Desk JUN 0 7 2006 LR-N06-0201 PSEG does not have specific schedule needs for this proposed change and processing can be pursued in accordance with the normal NRC review schedule for this type of request. PSEG requests implementation within 60 days of receipt of the approved amendment.

Should you have any questions regarding this request, please contact Mr. Jamie Mallon at (610) 765-5507.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on a714e Sincerely, (Dite) 44ýmasP. Joyce 1 Site Vice Presid 'nt Salem Generating Station Attachments (4)

Document Control Desk LR-N06-0201 JUN 0 7 2006 C Mr. S. Collins, Administrator - Region I U. S. Nuclear Regulatory Commission 475 Allendale Road King of Prussia, PA 19406 U. S. Nuclear Regulatory Commission Mr. Stewart Bailey, Project Manager - Salem Unit 1 and Unit 2 Mail Stop 08B1 Washington, DC 20555-0001 USNRC Senior Resident Inspector - Salem Unit 1 and Unit 2 (X24)

Mr. K.Tosch, Manager IV Bureau of Nuclear Engineering P. O. Box 415 Trenton, NJ 08625

ATTACHMENT 1 LCR S06-05 LR-N06-0201 SALEM GENERATING STATION - UNIT I AND UNIT 2 DOCKET NO. 50-272 AND 50-311 FACILITY OPERATING LICENSE NO. DPR-70 AND DPR-75 ELIMINATION OF REQUIREMENTS FOR HYDROGEN RECOMBINERS AND HYDROGEN ANALYZERS Table of Contents

1. INT R O DUC T IO N .................................................................................................. 1

2. DE S C R IPTIO N ..................................................................................................... 1

3. BA C KG R O UND .................................................................................................... 1

4. REGULATORY REQUIREMENTS AND GUIDANCE ....................................... 2

5. TECHNICAL ANALYSIS .................................................................................. 2

6. REGULATORY ANALYSIS .............................................................................. 2 6.1 Hydrogen Monitoring ............................................................................ 2 6.2 Inerted Containment ............................................................................... 2

7. NO SIGNIFICANT HAZARDS CONSIDERATION ........................................... 3

8. ENVIRONMENTAL EVALUATION ....................................................................  ;.. 3

9. PR EC ED ENT .................................................................................................. 3

10. R EFER EN C ES ................................................................................................ 3

ATTACHMENT 1 LCR S06-05 LR-N06-0201 CHANGE TO TECHNICAL SPECIFICATIONS

1.0 INTRODUCTION

The proposed License amendment deletes Technical Specification (TS) 3/4.6.4, "Combustible Gas Control," including TS 3/4.6.4.1, "Hydrogen Analyzers," and TS 3/4.6.4.2, "Electric Hydrogen Recombiners." The proposed TS changes support implementation of the revisions to 10 CFR 50.44, "Standards for Combustible Gas Control System in Light-Water-Cooled Power Reactors," that became effective on October 16, 2003.

The changes are consistent with Revision 1 of NRC-approved Industry/Technical Specification Task Force (TSTF) Standard Technical Specification (STS) Change Traveler, TSTF-447, "Elimination of Hydrogen Recombiners and Change to Hydrogen and Oxygen Monitors." The availability of this TS improvement was announced in the Federal Register on September 25, 2003, as part of the Consolidated Line Item Improvement Process (CLIIP). Salem Unit 1 and Unit 2 have not adopted STS; however, NRC Regulatory Issue Summary 2000-06, "CLIIP for Adopting STS Changes for Power Reactors," permits adoption of CLIIP changes for Licensees that have not converted to STS, but have determined that the TSTF is applicable to their facility.

2.0 DESCRIPTION

Consistent with the NRC-approved Revision 1 of TSTF-447, the proposed TS changes include:

TS 3/4.6.4 Combustible Gas Control Deleted TS 3/4.6.4.1 Hydrogen Analyzers Deleted TS 3/4.6.4.2 Electric Hydrogen Recombiners - W Deleted The elimination of the TS requirements above result in deletion of TS Bases 3/4.6.4, "Combustible Gas Control."

3.0 BACKGROUND

The background for this application is adequately addressed by the NRC Notice of Availability published on September 25, 2003, (68 FR 55416), Revision 1 to TSTF-447, and the documentation associated with the 10 CFR 50.44 rulemaking.

1

ATTACHMENT 1 LCR S06-05 LR-N06-0201 4.0 REGULATORY REQUIREMENTS AND GUIDANCE The applicable regulatory requirements and guidance associated with this application are adequately addressed by the NRC Notice of Availability published on September 25, 2003, (68 FR 55416), Revision 1 to TSTF-447, and the documentation associated with the 10 CFR 50.44 rulemaking.

5.0 TECHNICAL ANALYSIS

PSEG has reviewed the model safety evaluation (SE) published on September 25, 2003 (68 FR 55416), and verified its applicability as part of the CLIIP. This verification included a review of the NRC staffs model SE, as well as the information provided to support Revision 1 to TSTF-447.

PSEG has concluded that the justifications presented in the TSTF proposal and the model SE prepared by the NRC staff are applicable to Salem Unit 1 and Unit 2 and justify this amendment for the incorporation of the changes to the Salem Unit 1 and Unit 2 TS.

6.0 REGULATORY ANALYSIS

A description of this proposed change and its relationship to applicable regulatory requirements and guidance was provided in the NRC Notice of Availability published on September 25, 2003, (68 FR 55416), Revision 1 to TSTF-447, and the documentation associated with the 10 CFR 50.44 rulemaking.

As discussed in the model SE published in the Federal Register on September 25, 2003, (68 FR 55416) for this TS improvement, PSEG is making the following plant-specific verifications and commitments.

6.1 Hydrogen Monitoring PSEG has verified that a hydrogen monitoring system capable of diagnosing beyond design-basis accidents is installed in Salem Unit 1 and Unit 2. PSEG is making a regulatory commitment to maintain this capability. The hydrogen monitoring function will be included in the Salem Updated Final Safety Analysis Report. This regulatory commitment will be implemented in conjunction with the implementation of the proposed TS revision.

6.2 Inerted Containment Salem Unit 1 and Unit 2 do not have an inerted containment. Therefore, the need to verify and commit to oxygen monitors is not applicable for PSEG.

2

ATTACHMENT I LCR S06-05 LR-N06-0201 7.0 NO SIGNIFICANT HAZARDS CONSIDERATION PSEG has reviewed the proposed no significant hazards consideration determination published on September 25, 2003 (68 FR 55416) as part of the CLIIP. PSEG has concluded that the proposed determination presented in the notice is applicable to Salem Unit I and Unit 2, and the determination is hereby incorporated by reference to satisfy the requirements of 10 CFR 50.91(a).

8.0 ENVIRONMENTAL EVALUATION PSEG has reviewed the environmental evaluation included in the model SE published on September 25, 2003 (68 FR 55416) as part of the CLIIP. PSEG has concluded that the NRC staffs findings presented in that evaluation are applicable to Salem Unit I and Unit 2 and the evaluation is hereby incorporated by reference for this application.

9.0 PRECEDENT This application is being made in accordance with the CLIIP. PSEG is not proposing variations or deviations from the TS changes described in Revision 1 to TSTF-447 or the NRC staff's model SE published on September 25, 2003 (68 FR 55416).

10.0 REFERENCES

Federal Register Notice: Notice of Availability of Model Application Concerning Technical Specification Improvement To Eliminate Hydrogen Recombiner Requirement, and Relax the Hydrogen and Oxygen Monitor Requirements for Light Water Reactors Using the Consolidated Line Item Improvement Process, published September 25, 2003, (68 FR 55416).

3

ATTACHMENT 2 LCR S06-05 LR-N06-0201 TECHNICAL SPECIFICATION PAGES WITH PROPOSED CHANGES Salem Unit 1 Affected Page List Index Page VI Index Page XlII 314 6-14 through 17 The following Technical Specifications for Salem Unit 1 Facility Operating License DPR-70 are affected by this change request:

Technical Specification Page 3/4.6.4, "Combustible Gas Control" 3/4 6-18 3/4.6.4.1, "Hydrogen Analyzers" 3/4 6-18 3/4.6.4.2, "Electric Hydrogen Recombiners - W' 3/4 6-19 Salem Unit 2 Affected Page List Index Page VI Index Page XIII 3/4 6-16 through 19 3/4 6-20 The following Technical Specifications for Salem Unit 2 Facility Operating License DPR-75 are affected by this change request:

Technical Specification Page 3/4.6.4, "Combustible Gas Control" 3/4 6-21 3/4.6.4.1, "Hydrogen Analyzers" 3/4 6-21 3/4.6.4.2, "Electric Hydrogen Recombiners - W' 3/4 6-22

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3/4.5.1 ACCUMULATORS .... ........................................... 3/4 5-1 3/4.5.2 ECCS SUBSYSTEMS - Tavg Ž 350FF ................................ 3/4 5-3 3/4.5.3 ECCS SUBSYSTEMS - Tavg < 350FF ................................ 3/4 5-6 3/4.5.4 SEAL INJECTION FLOW ......................................... 3/4 5-6b 3/4.5.5 REFUELING WATER STORAGE TANK ................................. 3/4 5-7 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Containment Integrity .................................... 3/4 6-1 Containment Leakage ...................................... 3/4 6-2 Containment Air Locks .................................... 3/4 6-5 Internal Pressure ........................................ 3/4 6-6 Air Temperature ........................................... 3/4 6-7 Containment Structural Integrity ......................... 3/4 6-8 Containment Ventilation System ........................... 3/4 6-8a 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS Containment Spray System ................................. 3/4 6-9 Spray Additive System .................................... 3/4 6-10 Containment Cooling System ............................... 3/4 6-11 3/4.6.3 CONTAINMENT ISOLATION VALVES .................................. 3/4 6-12 3/4.6.4 COMBUSTIBLE GAS CONTROL Hydrogen .......................................

Hydrogen Analyzers Electric Recombiners .............................. 3/4 6-18 3/4 6-198 Deleted SALEM - UNIT 1 VI Amendment No. 225

INDEX BASES SECTI ON PAGE 3/4.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3/4.5 .1 ACCUMULATORS ........ .................... .B 3/4 5-1 3/4.5.2 and ECCS SUBSYSTEMS ........... ................ B 3/4 5-1 3/4.5.3 3/4.5.4 SEAL INJECTION FLOW ............. .B 3/4 5-2 I 3/4.5.5 REFUELING WATER STORAGE TANK (RWST) ..... .B 3/4 5-2 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT ........ .............. B 3/4 6-1 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS ......... ..B 3/4 6-3 3/4.6.3 CONTAINMENT ISOLATION VALVES ...... .......... B 3/4 6-3 3/4.6.4 COMBUSTIBLE GAS CONTROL .......... ............ B 3/4 6-4

... . .D

.. e le ted SALEM - UNIT 1 XIII Amendment No. 225 I

I 19 I

PAGES 3/4 6-14 THROUGH 3/4 6 ARE INTENTIONALLY LEFT BLANK SALEM - UNI*T 3/4 6-14 through-15// Amendment No).189

314..4 C COMBUSTIBLE NTAINMENT SYSTEMS GAS CONTROL This Page

• / Deleted HYDRO\GN ANALYZERS/

LIMITING ONDITION FOR OPERATION 3.6.4.1 Two independent containment hydrogen analyzers shall be OP BLE.

APPLICABILITY: DES 1 and 2.

ACTION:

With one hydrogen ana yzer inoperable, restore the inoperable analyzer to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

With both hydrogen analyze s inoperable, restore at leas one analyzer to OPERABLE status within 72 h urs or be in at least HOT S ANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.4.1 Each hydrogen analyzer shal be demon trated OPERABLE by the perfornance of:

a. a CHANNEL CHECK at least once per 12 rs;

b. a CHANNEL FUNCTIONAL TEST at least ce er 92 days;

c. a gas calibration* at least once er 92 d s using sample gases containiig:

1. Two volume percent hydro n (low span) balance Nitrogen, and

2. Six volume percent hydr en (high span), balance Nitrogen.

d. a CHANNEL CALIBRATION at le st once per refuelin using sample gases containing:

1. Two volume percen hydrogen (low span), balanc Nitrogen, and

2. Six volume perce t hydrogen (high span), balanc Nitrogen.

• The hydrogen sensor s calibration shall consist of all lements of the CHANNEL CALIBRATION, w h the exception that only a single pont comparison heck for reasonableness (b comparison to other installed plant ins umentation) s required to check th hydrogen analyzer temperature and pressur sensors. I SALEM - UNIT 3/4 6-18 Amendment No. 71

C\TAINMENT SYSTEMS This Page Deleted ELE RIC HYDROGEN RECOMBINERS - W _____ _/

LIMITIP CONDITION FOR OPERATION 3.6.4.2 T independent containment hydrogen recombiner systems shall be OPERABLE.

APPLICABILITY: ODES 1 and 2.

ACTION:

With one hydrogen re ombiner system inoperable, restore the inop rable system to OPERABLE status withi 30 days or be in at least HOT STANDBY wi hin the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.4.2 Each hydrogen recombi er system shall be dem strated OPERABLE:

a. At least once per 6* mo ths by verifying ring a recombiner system functional tes t t the minimum eater sheath temperature increases to ; 700OF witi 90 minutes nd (upon reaching 700*F) verifying that, after ire sing the wer setting to maximum power for 2 minutes, the power meter r ds ý 6 kW.

b. At least once per 18 months by:

1. Performing a CHANNEL CALI ON of all recombiner instrumentation and cont 1 ci cuits.

2. Verifying through a vi ual exami tion that there is no evidence of abnormal condi ons within e recombiner enclosures (i.e., 1 se wiring or s ructural connections, deposits of foreig materials, etc.)

3. Verifying durin a recombiner system fu ctional test that the heater she th temperature increases o : 1200*F within 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> and is aintained for at least 4 ho s.

4. Verifying e integrity of all heater electr al circuits by performin a continuity and resistance to gro d test following the abov required function test. The resistan e to ground for any he er phase shall be ý 10,000 ohms.

• NOTE: The re irements of this 6 month system functional tes can be met by satis actory completion of the 18 month system functio al test in Specificat' n 4.6.4.2.b on those occasions where performance o both tests wou d be required at or near the same time.

SALEM - UNIT 3/4 6-19 Amendment 141

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3/4.5.1 ACCUMULATORS ......................................... 3/4 5-1 3/4.5.2 ECCS SUBSYSTEMS - Tavg Ž 350OF ......................... 3/4 5-3 3/4.5.3 ECCS SUBSYSTEMS - Tavg < 350OF ......................... 3/4 5-7 3/4.5.4 SEAL INJECTION FLOW .................................. 3/4 5-8a 3/4.5.5 REFUELING WATER STORAGE TANK ......................... 3/4 5-9 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Containment Integrity ................................ 3/4 6-1 Containment Leakage .................................. 3/4 6-2 Containment Air Locks ................................ 3/4 6-4 Internal Pressure .................................... 3/4 6-6 Air Temperature ...................................... 3/4 6-7 Containment Structural Integrity ...................... 3/4 6-8 Containment Ventilation System ........................ 3/4 6-9 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS Containment Spray System ............................. 3/4 6-10 Spray Additive System ................................ 3/4 6-11 Containment Cooling System ........................... 3/4 6-12 3/4.6.3 CONTAINMENT ISOLATION VALVES ......................... 3/4 6-14

/464 COMBUSTIBLE GSCONTROL Hydrogen Analyzers ..... ............................... 3/4 6-21 Electric Hydrogen Recombiners ........................ 3/4 62 Deleted SALEM - UNIT 2 VI Amendment No. 159

INDEX BASES SECTION PAGE 3/4.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3/4.5.1 ACCUMULATORS .......................................... B 3/4 5-1 3/4.5.2 and ECCS SUBSYSTEMS ....................................... B 3/4 5-1 3/4.5.3 3/4.5.4 SEAL INJECTION FLOW ................................... B 3/4 5-2 3/4.5.5 REFUELING WATER STORAGE TANK (RWST) .................... B 3/4 5-3 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT ................................... B 3/4 6-1 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS .................. B 3/4 6-3 3/4.6.3 CONTAINMENT ISOLATION VALVES .......................... B 3/4 6-4 3/4.6.4 COMBUSTIBLE GAS CONTROL ............................... B 3/4 6-4 SALEM - UNIT 2 XIII Amendment No.206

22 PAGES 3/4 6-16 THROUGH 3/4 6- ARE INTENTIONALLY BLANK.

SALEM - UNIT 2 3/4 6-16 through 6/ Amendment No. 172 I

INTENTIONALLY BLANK

- UNIT 2 3/4 6-20 Amendment 128

PAGE INTENTIONALLY LEFT

&NTAINMENT SYSTEMS This Page Deleted 3/4\.4 COMBUSTIBLE GAS CONTROL-- -/

HYDROGE ANALYZERS/

LIMITING NDITION FOR OPERATION 3.6.4.1 Tw independent containment hydrogen analyzers shall be OPE LE.

APPLICABILITY: ODES 1 and 2.

ACTION:

With one hydrogen an lyzer inoperable, restore the inoperable nalyzer to OPERABLE status withi 30 days or be in at least HOT STANDBY ithin the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

With both hydrogen analyz s inoperable, restore at leas one analyzer to OPERABLE status within 72 h urs or be in at least HOT S NDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.4.1 Each hydrogen analyzer shall e dem strated OPERABLE by the perfornance of:

a. a CHANNEL CHECK at least once per 12 ours;

b. a CHANNEL FUNCTIONAL TEST at leas once er 92 days;

c. a gas calibration* at least onc per 92 da using sample gases containiig:

1. Two volume percent hyd ogen (low span), balance Nitrogen, and

2. Six volume percent h rogen (high span), alance Nitrogen.

d. a CHANNEL CALIBRATION at east once per refueling using sample gases containing:

1. Two volume per ent hydrogen (low span), balance Nitrogen, and

2. Six volume p cent hydrogen (high span), balance itrogen.

The hydrogen sens r gas calibration shall consist of all e ements of the CHANNEL CALIBRATIO , with the exception that only a single poi t comparison 3heck for reasonablenes (by comparison to other installed plant inst entation) Ls required to chec the hydrogen analyzer temperature and pressure ensors.

SALEM -/UNIT 2 3/4 6-21 Amendment No.

CQNTAINMENT SYSTEMS This Page Deleted ELEXIC HYDROGEN RECOMBINERS - W _*/

LIMITI GCONDITION FOR OPERATION/

3.6.4.2 wo independent containment hydrogen recombiner systems shall e OPERABLE.

APPLICABILIT MODES 1 and 2.

ACTION:

With one hydrogen ecombiner system inoperable, restore the i operable system to OPERABLE status wit in 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMEN S 4.6.4.2 Each hydrogen re mbiner system shall be dem nstrated OPERABLE:

a. At least once per 6* m ths by verifying dur g a recombiner system functional test that the minim m heater sheath t perature increases to > 700*F within 90 minutes and (upon rea ing 700*F) ver ying that, after increasing the power setting to maximum power f 2 minutes, he power meter reads > 60 kW.

b. At least once per 18 months b :

1. Performing a CHANNEL CAMIBRATIO o all recombiner instrumentation and control circuits.

2. Verifying through a visual exa inati n that there is no evidence of abnormal conditions within the reco iner e closures (i.e., loose wiring or structural connections, deposits foreign terials, etc.)

3. Verifying, during a reco iner system fun tional test, that the heater sheath temperature increases o > 1200*F within hours and is maintained for at least 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

4. Verifying the integ t of all heater electric circuits by performing a resistance to ground tes following the above require functional test. The resistance to ground f any heater phase shall be grea er than or equal to

• NOTE: The re irements of this 6 month system functio al test can be met by satisfactory comp etion of the 8 month system functional te in Specification 4.6.4.2.b on th e occasions where performance of both tests uld be required at or near the sa e time.

SALEM - NIT 2 3/4 6-22 Amendment o. 120

ATTACHMENT 3 LCR S06-05 LR-N06-0201 LIST OF REGULATORY COMMITMENTS The following table identifies those actions committed to by PSEG in this document. Any other statements in this submittal are provided for information only purposes and are not considered to be regulatory commitments. Please direct questions regarding these commitments to Mr. Jamie Mallon at (610) 765-5507.

Regulatory Commitment Due Date/Event PSEG will maintain the hydrogen monitoring system Concurrent with capability of diagnosing beyond design basis accidents. implementation of the amendment PSEG will include the hydrogen monitoring function in the Concurrent with Salem Updated Final Safety Analysis Report. implementation of I I the amendment

ATTACHMENT 4 LCR S06-05 LR-N06-0201 PROPOSED CHANGES TO TS BASES PAGES The following Technical Specifications Bases for Salem Unit I and Unit 2, Facility Operating License No. DPR-70 and DPR-75, are affected by this change request:

Salem Unit I Technical Specification PaQe Bases 3/4.6.4 B 3/4 6-4 Salem Unit 2 Technical Specification Paqe Bases 3/4.6.4 B 3/4 6-4

ATTACHMENT 4 LCR S06-05 LR-N06-0201 CONTAINMENT SYSTEMS BASES valve response time test ensures that on a loss of offsite power, each discharge valve actuates to the open position in accordance with the design to allow sufficient tank discharge into CFCU piping to maintain water filled, subcooled fluid conditions in three CFCU cooling loops, assuming the most limiting single failure.

3/4.6.3 CONTAINMENT ISOLATION VALVES The OPERABILITY of the containment isolation valves ensures that the containment atmosphere will be isolated from the outside environment in the event of a release of radioactive material to the containment atmosphere or pressurization of the containment.

Containment isolation within the time limits specified ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a LOCA.

The opening of locked or sealed closed containment isolation valves (penetration flow paths)on an intermittent basis under administrative control includes the following considerations: (1) stationing a dedicated individual, who is in constant communication with the control room, at the valve controls, (2) instructing this individual to close these valves in an accident situation, and (3) assuring that environmental conditions will not preclude access to close the valves and that this action will prevent the release of radioactivity outside the containment.

The main steam isolation valves (MSIVs) fulfill their containment isolation function as remote-manual containment isolation valves. The automatic closure of the MSIVs is not required for containment isolation due to having a closed system inside containment. The remote-manual containment isolation function of the MSIVs can be accomplished through either the use of the hydraulic operator or when the MSIV has been tested in accordance with surveillance requirement 4.7.1.5 the steam assist function can be credited.

Surveillance Requirement (SR) 4.6.3.1.3 only applies to the MS7 (Main Steam Drain) valves and the MS18 (Main Steam Bypass) valves. The MS167 (Main Steam Isolation) valves are tested for main steam isolation purposes by SR 4.7.1.5. For containment isolation purposes, the MSI67s are tested as remote/manual valves pursuant to Specification 4.0.5.

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ATTACHMENT 4 LCR S06-05 LR-N06-0201 CONTAINMENT SYSTEMS BASES The surveillance requirements for the service water accumulator vessels ensure each tank contains sufficient water and nitrogen to maintain water filled, subcooled fluid conditions in three containment fan coil unit (CFCU) cooling loops in response to a loss of offsite power, without injecting nitrogen covergas into the containment fan coil unit loops assuming the most limiting single failure. The surveillance requirement for the discharge valve response time test ensures that on a loss of offsite power, each discharge valve actuates to the open position in accordance with the design to allow sufficient tank discharge into CFCU piping to maintain water filled, subcooled fluid conditions in three CFCU cooling loops, assuming the most limiting single failure.

3/4.6.3 CONTAINMENT ISOLATION VALVES The OPERABILITY of the containment isolation valves ensures that the containment atmosphere will be isolated from the outside environment in the event of a release of radioactive material to the containment atmosphere or pressurization of the containment. Containment isolation within the time limits specified ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a LOCA.

The opening of locked or sealed closed containment isolation valves (penetration flow paths) on an intermittent basis under administrative control includes the following considerations: (1) stationing a dedicated individual, who is in constant communication with the control room, at the valve controls, (2) instructing this individual to close these valves in an accident situation, and (3) assuring that the environmental conditions will not preclude access to close the valves and that this action will prevent the release of radioactivity outside the containment.

The main steam isolation valves (MSIVs) fulfill their containment isolation function as remote-manual containment isolation valves. The automatic closure of the MSIVs is not required for containment isolation due to having a closed system inside containment. The remote-manual containment isolation function of the MSIVs can be accomplished through either the use of the hydraulic operator or when the MSIV has been tested in accordance with surveillance requirement 4.7.1.5 the steam assist closure function can be credited.

Surveillance Requirement (SR) 4.6.3.3 only applies to the MS7 (Main Steam Drain) valves and the MS18 (Main Steam Bypass) valves. The MS167 (Main Steam Isolation) valves are tested for main steam isolation purposes by SR 4.7.1.5.

For containment isolation purposes, the MSI67s are tested as remote/manual valves pursuant to Specification 4.0.5.

S3/4.6.4 SLI COMBUSTIBLE 2B3 GAS CONTROL-----**

6- R is Deleteded

~The OPERABILITY of the equipment and systems required for the detect/ion and control of hydrogen gas ensures that this equipment will be available to*

/maintain the hydrogen concentration within containment below its flammable Slimit during post-LOCA conditions. Either recombiner unit is capable of k*controlling the expected hydrogen generation associated with 1) zirconium-water/

/ reactions, 2) radiolytic decomposition of water, and 3) corrosion of metals /

Swithin containment. These hydrogen control systems are consistent with the/

recommendations of Regulatory Guide 1.7, "Control of CombustibleG oncentrations in Containment Following a LOC" 971.h SALEM - UNIT 2 B 3/4 6-4 Revised by letter dated 6-19-2003