Text

R.E. Ginna - Supplemental Information Regarding TSTF-425 License Amendment Request
	ML15275A276
Person / Time
Site:	Ginna
Issue date:	10/02/2015
From:	Jim Barstow; Exelon Generation Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	GL-08-001, TAC MF4405, TAC MF4406, TAC MF4407, TAC MF4409
	Download: ML15275A276 (45)
	v • d • e

Exelon Generation October 2, 2015 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 R. E. Ginna Nuclear Power Plant Renewed Facility Operating License No. DPR-18 NRC Docket No. 50-244 200 Exelon Wiy Kennett Square PA 19348 www.exeloncorp.com 10 CFR 50.90

Subject:

Supplemental Information Regarding TSTF-425 License Amendment Request

References:

1. Letter from David T. Gudger (Exelon) to U.S. Nuclear Regulatory Commission, dated July 10, 2014: Application to Revise Technical Specifications to Adopt TSTF-523, "Generic Letter 2008-01 , Managing Gas Accumulation," using the Consolidated Line Item Improvement Process 2. Letter from James Barstow (Exelon) to U.S. Nuclear Regulatory Commission, dated June 4, 2015: Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) 3. Letter from U.S. Nuclear Regulatory Commission to Dave T. Gudger (Exelon), dated July 30, 2015: Calvert Cliffs Nuclear Power Plant , Unit Nos. 1 and 2; R.E. Ginna Nuclear Power Plant; and Nine Mile Point Nuclear Station , Unit No. 2 -Issuance of Amendments Regarding Implementation of Technical Specification Task Force Traveler 523 , "Generic Letter 2008-01 , Managing Gas Accumulation" (TAC Nos.

MF4405, MF4406, MF4407, and MF4409) On July 10, 2014, Exelon Generation Company, LLC (Exelon) submitted a license amendment request (Reference

1) to adopt Technical Specification Task Force 523 (TSTF-523) "Generic Letter 2008-01, Managing Gas Accumulation." On June 4, 2015, Exelon submitted a license amendment request (Reference

2) for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) to adopt TSTF-425.

Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Page2 On July 30, 2015, the U.S Nuclear Regulatory Commission (NRC) issued Amendment 118 to the R. E. Ginna Nuclear Power Plant (Ginna) Technical Specifications (TS) approving the implementation of TSTF-523.

This amendment added new Surveillance Requirements (SR) and modified the language of existing surveillances (Reference 3). This letter supplements the original submittal for TSTF-425 (Reference

2) to: 1. Include the new surveillances added to the Ginna TS as a result of implementing Amendment 118, TSTF-523; and 2. Update previously submitted surveillances whose language was modified as a result of implementing Amendment 118, TSTF-523 ,. Exelon recognizes that the added surveillances with its associated surveillance frequencies are deviations from the approved TSTF-425 because they were not included in the NUREG-1431 mark-ups provided in TSTF-425.

However, Exelon has determined that relocating the frequencies for these new Ginna surveillances is consistent with TSTF-425, Revision 3, and with the NRC staff's model Safety Evaluation (SE) dated July 6, 2009 (74 FR 31996), including the scope exclusions identified in the model SE. Specifically , these surveillances are not: 1. Frequencies that reference other approved programs for the specific interval (such as the lnservice Testing Program or the Primary Containment Leakage Rate Testing Program);

2. Frequencies that are purely event driven (e.g., "Each time the control rod is withdrawn to the 'full out' position");

3. Frequencies that are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after thermal power reaching 95% RTP"); and 4. Frequencies that are related to specific conditions (e.g., battery degradation, age, and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease").

These surveillances involve fixed periodic frequencies, and in accordance with TSTF-425, changes to the frequencies for these surveillances would be controlled under the Surveillance Frequency Control Program (SFCP). The SFCP provides the necessary administrative controls to require that surveillances related to testing, calibration and inspection are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Furthermore, TSTF-523 recognized that these new SR frequencies are within the scope of TSTF-425.

As shown in the marked-up pages of TSTF-523, the surveillance frequency requirements were stated as either "In accordance with the Surveillance Frequency Control Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Page 3 Program" for licensees with an approved SFCP, or "31 days" for licensees without an approved SFCP; thus implicitly recognizing that these surveillances were within the scope of TSTF-425.

Attachment 1 contains a brief description of the surveillances added and the surveillances language modified by Reference

2. Surveillances whose text was modified by the issuance of TSTF-523 do not represent a deviation from TSTF-425; however, they are included only for completeness of information.

Added surveillances are shown underlined and in bolded text. Attachment 2 contains the original TSTF-425 (NUREG-1431) vs Ginna Cross-Reference revised to include the new surveillances.

The new information is shown in red text. Attachment 3 contains the original submitted marked-up TS pages per TSTF-425 revised to include the new or modified surveillances.

New and modified surveillances are highlighted in yellow. Attachment 4 contains the original submitted marked-up TS Bases pages per TSTF-425 with the new Bases shown as inserts A through G, as applicable.

Attachment 5 contains the proposed new Bases statements (Inserts A through G) as described in TSTF-523.

Exelon has reviewed the information supporting a finding of No Significant Hazards consideration provided to the NRC in Reference

1. The additional information provided in this supplement does not affect the bases for concluding that the proposed license amendment does not involve a significant hazards consideration.

Furthermore, the additional information provided in this supplement does not affect the bases for concluding that neither an environmental impact statement nor an environmental assessment needs to be prepared in connection with the proposed amendment.

No regulatory commitments are contained in this letter. If you should have any questions regarding this submittal, please contact Enrique Villar at 610-765-5736.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the 2nd day of October 2015. Respectfully, Director -Licensing

& Regulatory Affairs Exelon Generation Company, LLC Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Page 4 Attachments:

1. Description of Affected Surveillances as Modified by Reference 3 cc: 2. Revised TSTF-425 (NUREG-1431) vs. Ginna Cross-Reference

3. Marked up Technical Specification Pages as Modified by Reference 3 4. Marked up Technical Specifications Bases Pages as Modified by Reference 3 5. Proposed Technical Specification Bases Description per Reference 3 USNRC Region I, Regional Administrator USNRC Senior Resident Inspector

-Ginna USNRC Project Manager, NRR -Ginna A. L. Peterson, NYSERDA w/attachments ATTACHMENT 1 Supplement to License Amendment Request R. E. Ginna Nuclear Power Plant Docket No. 50-244 Application for Technical Specification Change Regarding Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Description of Affected Surveillances as Modified by Reference 3

Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Attachment 1 Page 1 of 2 DESCRIPTION OF AFFECTED SURVEILLANCES AS MODIFIED BY REFERENCE 2 (1) Added SR 3.4.6.4, which states, Verify required AHR loop locations susceptible to gas accumulation are sufficiently filled with water. With a note that states: Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4. And a frequency of 31 days (2) Added SR 3.4 .. 7.4, which states, Verify required AHR loop locations susceptible to gas accumulation are sufficiently filled with water. With a frequency of 31 days (3) Added SR 3.4.8.3, which states Verify AHR loop locations susceptible to gas accumulation are sufficiently filled with water. With a frequency of 31 days (4) Added a note to SR 3.5 .. 2.2, which states: Not required to be met for system vent flow paths opened under administrative control. (5) Added SR 3.5.2.8, which states, Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water. With a frequency of 31 days (6) Added a note to SR 3.6.6.2, which states: Not required to be met for system vent flow paths opened under administrative control.

Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 (7) Added SR 3.6.6 .. 16, which states, Attachment 1 Page 2 of 2 Verify CS locations susceptible to gas accumulation are sufficiently filled with water. With a frequency of 31 days (8) Added SR 3.9.4.2, which states, Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water. With a frequency of 31 days (9) Added SR 3.9.5.3, which states, Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water. With a frequency of 31 days ATTACHMENT 2 Supplement to License Amendment Request R. E. Ginna Nuclear Power Plant Docket No. 50-244 Application for Technical Specification Change Regarding Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Revised TSTF-425 (NUREG-1431) vs. Ginna Cross-Reference Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 TSTF-425 CNUREG-1431) vs. Ginna Cross-Reference Technical Specification Section Title/Surveillance Description*

TSTF-425 Definitions

1.1 Staaaered

Test Testing Shutdown margin (SOM) 3.1.1 Verify SOM within limits 3.1.1.1 Core Reactivity

3.1.2 Verify

core reactivity within predicted value 3.1.2.1 Rod Group Alignment Limits 3.1.4 Verify individual rod position within alignment 3.1.4.1 Verify rod freedom of movement (trippability) 3.1.4.2 Verify individual rod position within alignment with rod position -------------

monitor inoperable Shutdown Bank Insertion Limits 3.1.5 Verify shutdown bank within insertion limit per COLR 3.1.5.1 Control Bank Insertion Limit 3.1.6 Verify control bank within insertion limit per COLR 3.1.6.2 Verify sequence and overlap limits per COLR 3.1.6.3 Verify control bank within insertion limit per COLR when insertion

limit monitor inoperable Physics Tests (Exceptions Mode 2) 3.1.8 Verify RCS lowest loop temperature 3.1.8.2 Verify thermal power 3.1.8.3 Verify SOM within COLR 3.1.8.4 Fa(Z) 3.2.1 Verify measured Fa(Z) 3.2.1.1 Verify measured Fw xv <F 1 xv 3.2.1.2 Fa(Z) (RAOC-W(Z)

Methodology 3.2.1B Verify F ca(Z) is within limit 3.2.1.1 Verify F w 0 (Z) is within limit 3.2.1.2 Fa(Z) (CAOC-W(Z)

Methodology 3.2.1C Verify F c 0 (Z) is within limit 3.2.1.1 Verify F wa(Z) is within limit 3.2.1.2 Nuclear Enthalpy Rise Hot Channel Factor (FN dhl 3.2.2 Verify Fdh within limits per COLR 3.2.2.1 Verify Fdh within limits per COLR (only when one power range -------------

inoperable)

AFD 3.2.3A/B Verify AFD is within limits 3.2.3.1 Update tarQet flux difference 3.2.3.2 Determine by measurement target flux difference 3.2.3.3 AFD(RAOC Methodology) 3.2.3B Verify AFD is within limits 3.2.3.1 Attachment 2 Page 1 of 11 GINNA 1.1 3.1.1 3.1.1.1 3.1.2 3.1.2.2 3.1.4 3.1.4.1 3.1.4.3 3.1.4.2 3.1.5 3.1.5.1 3.1.6 3.1.6.2 3.1.6.4 3.1.6.3 3.1.8 3.1.8.2 3.1.8.3 3.1.8.4 -------------

3.2.1 3.2.1.1 3.2.1.2 -------------

3.2.2 3.2.2.1 3.2.2.2 -------------

3.2.3 3.2.3.1 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

QPTR Verify QPTR within limits by calculation Verify QPTR within limits by incore detectors RTS Instrumentation Channel Check Compare calorimetric to power ranqe channel output Compare results of incore to NIS Perform T ADOT Perform ACTUATION LOGIC TEST Calibrate excore channels to agree with incore Perform COT Perform COT Perform T ADOT Channel Calibration Channel Calibration (Neutron detectors excluded)

Channel Calibration (Include resistance temperature detector)

Perform COT Perform T ADOT Perform T ADOT (verification of setpoint is not required)

Verify RTS time response ESFAS Instrumentation Channel Check Perform Actuation Logic Test Perform Actuation Loqic Test (continuity may be excluded)

Perform Master Relay Test Perform COT Perform Slave Relay Test Perform T ADOT Perform TADOT (setpoint verification not required for manual functions)

Channel Calibration ESFAS Time Response Verify pressurizer pressure low and steam line pressure low NOT bypassed PAM Instrumentation Channel Check Channel Calibration Remote Shutdown System Channel Check Verify control circuit and transfer switch functional Channel Calibration Perform TADOT (reactor trip breakers)

LOP DG Start Instrumentation Channel Check Perform T ADOT TSTF-425 3.2.4 3.2.4.1 3.2.4.2 3.3.1 3.3.1.1 3.3.1.2 3.3.1.3 3.3.1.4 3.3.1.5 3.3.1.6 3.3.1.7 3.3.1.8 3.3.1.9 3.3.1.10 3.3.1.11 3.3.1.12 3.3.1.13 3.3.1.14 3.3.1.15 3.3.1.16 3.3.2 3.3.2.1 3.3.2.2 3.3.2.3 3.3.2.4 3.3.2.5 3.3.2.6 3.3.2.7 3.3.2.8 3.3.2.9 3.3.2.10 Attachment 2 Page 2 of 11 GINNA 3.2.4 3.2.4.1 3.2.4.2 3.3.1 3.3.1.1 3.3.1.2 3.3.1.3 3.3.1.4 3.3.1.5 3.3.1.6 3.3.1.7 3.3.1.8 3.3.1.9 -------------3.3.1.10 --------------

3.3.1.13 3.3.1.11 ----------------------------

3.3.2 3.3.2.1 3.3.2.7 --------------

3.3.2.7 3.3.2.2 3.3.2.7 3.3.2.3 3.3.2.4 3.3.2.5 3.3.2.7 --------------3.3.2.6 3.3.3 3.3.3 3.3.3.1 3.3.3.1 3.3.3.2 3.3.3.2 3.3.4 --------------

3.3.4.1 --------------

3.3.4.2 --------------3.3.4.3 --------------

3.3.4.4 --------------3.3.5 3.3.4 3.3.5.1 --------------3.3.5.2 3.3.4.1 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description Channel Calibration Containment Purge and Exhaust Isolation Instrumentation Channel Check Perform Actuation Looic Test Perform Master Relay Test Perform Actuation Logic Test (applicable to ESFAS instrumentation)

Perform Master Relav Test Perform COT Perform Slave Relay Test Perform TADOT (validation of setpoint not required)

Channel Calibration Containment Ventilation Isolation Instrumentation Channel Check Perform COT Perform Actuation Logic Test Channel Calibration CREFS Actuation Instrumentation Channel Check Perform COT Perform Actuation Logic Test Perform Master Relay Test Perform Actuation Logic Test (applicable to ESFAS instrumentation)

Perform Master Relay Test (applicable to ESFAS instrumentation)

Perform Slave Relay Test Perform TADOT (validation of setpoint not required)

Channel Calibration CREATS Actuation Instrumentation Channel Check Perform COT Perform T ADOT Channel Calibration Perform Actuation Looic Test FBACS Actuation Instrumentation Channel Check Perform COT Perform Actuation Logic Test Perform TADOT (validation of setpoint not required)

Channel Calibration BOPS Channel Check Perform COT Channel Calibration RCS Pressure, Temperature, and Flow DNB Limits Attachment 2 Page 3of11 TSTF-425 GINNA 3.3.5.3 3.3.4.2 3.3.6 --------------

3.3.6.1 --------------

3.3.6.2 --------------

3.3.6.3 --------------

3.3.6.4 --------------

3.3.6.5 --------------

3.3.6.6 --------------

3.3.6.7 --------------

3.3.6.8 --------------

3.3.6.9 -------------

3.3.5 --------------

3.3.5.1 --------------

3.3.5.2 --------------

3.3.5.3 --------------

3.3.5.4 3.3.7 --------------

3.3.7.1 --------------

3.3.7.2 --------------

3.3.7.3 --------------

3.3.7.4 --------------

3.3.7.5 --------------

3.3.7.6 --------------

3.3.7.7 --------------

3.3.7.8 --------------

3.3.7.9 --------------

3.3.6 --------------

3.3.6.1 --------------

3.3.6.2 --------------

3.3.6.3 --------------

3.3.6.4 --------------

3.3.6.5 3.3.8 --------------

3.3.8.1 --------------

3.3.8.2 --------------

3.3.8.3 --------------

3.3.8.4 --------------

3.3.8.5 --------------

3.3.9 --------------

3.3.9.1 --------------

3.3.9.2 --------------

3.3.9.3 --------------

3.4.1 3.4.1 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

Verify pressurizer pressure per COLR Verify RCS average temperature per COLR Verify RCS total flow rate per COLR Verify by heat balance that RCS total flow rate per COLR RCS Minimum Temperature for Criticality Verify RCS averaoe temperature in each loop Verify RCS average temperature in each loop Only required if Tave alarm is inoperable and RCS loop Tave <f547l RCS PIT Limit Verify RCS pressure, temperature, heat up and cooldown rates per PTLR RCS Loops -MODES 1 and 2 Verify each RCS loop is in operation RCS Loops -MODES 1 >8.5% RTP Verify each RCS loop is in operation RCS Loops -MODES 1 :S 8.5% RTP, 2 and 3 Verify required RCS loop is in operation Verify steam oenerator secondary side water level Verify correct breaker alignment and power to required RCP pump RCS Loops -MODE 3 Verify required RCS loops are in operation Verify steam generator water level Verify correct breaker alignment and power to pumps RCS Loops -MODE 4 Verify required RCS or RHR loop is in operation Verify steam generator water level Verify correct breaker alionment and power to pump Verify locations susceptible to gas accumulation are filled RCS Loops -MODE 5, Loops Filled Verify required RHR loop is in operation Verify steam generator secondary side water level Verify correct breaker alignment and power to required RHR pump Verify locations susceptible to oas accumulation are filled RCS Loops -MODE 5, Loops Not Filled Verify required RHR loop is in operation Verify correct breaker alignment and power to RHR pump Verify locations susceptible to oas accumulation are filled Pressurizer Verify pressurizer water level Verify capacity of each group of pressurizer heaters Verify required pressurizer heaters capable being powered by emergency power Pressurizer PORVs Cycle each block valve Cycle each PORV Attachment 2 Page 4 of 11 TSTF-425 GINNA 3.4.1.1 3.4.1.1 3.4.1.2 3.4.1.2 3.4.1.3 3.4.1.3 3.4.1.4 --------------

3.4.2 3.4.2 3.4.2.1 ------------

3.4.2.2 3.4.3 3.4.3 3.4.3.1 3.4.3.1 3.4.4 --------------

3.4.4.1 --------------

3.4.4 --------------

3.4.4.1 --------------

3.4.5 --------------

3.4.5.1 --------------

3.4.5.2 --------------

3.4.5.3 3.4.5 --------------3.4.5.1 --------------

3.4.5.2 --------------

3.4.5.3 --------------

3.4.6 3.4.6 3.4.6.1 3.4.6.1 3.4.6.2 3.4.6.2 3.4.6.3 3.4.6.3 ------------

3.4.6.4 3.4.7 3.4.7 3.4.7.1 3.4.7.1 3.4.7.2 3.4.7.2 3.4.7.3 3.4.7.3 ------------

3.4.7.4 3.4.8 3.4.8 3.4.8.1 3.4.8.1 3.4.8.2 3.4.8.2 ------------

3.4.8.3 3.4.9 3.4.9 3.4.9.1 3.4.9.1 3.4.9.2 3.4.9.2 3.4.9.3 ----------------

3.4.11 3.4.11 3.4.11.1 3.4.11.1 3.4.11.2 3.4.11.2 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

Cycle each solenoid air control valve Verify PORVs and block valves capable being powered by emergency power LTOP System Verify no SI pump capable of injecting Verify maximum of [one] [HPI] pump capable of injecting Verify maximum of charqinq pump capable of iniectinq Verify each accumulator is isolated Verify AHR suction valve is open Verify RCS vent path Verify (required)

PORV block valve open Verify AHR suction valve is locked open and power removed Perform COT (excludinq actuation)

Verify power removed from each ECCS accumulator MOV Channel Calibration RCS Operational Leakage Verify RCS operational leakage within limits Verify primary to secondary leakage within limits RCS PIV Leakage Verify leakage from each RCS PIV Verify AHR interlock functionality (opening)

Verify AHR interlock functionality (closure)

RCS Leakage Detection Instrumentation Channel Check Perform COT (atmosphere radioactivity monitor) Channel Calibration (containment sump monitor) Channel Calibration (containment atmosphere monitor) Channel Calibration (containment air cooler flow rate monitor) RCS Specific Activity Verify qross specific activity Verify Dose Equivalent 1-131 Determine E RCS Loop Isolation Valves Verify loop isolation valve is open and power removed RCS Loops -Test Exceptions Verify thermal power is <P-7 Accumulators Verify accumulator isolation valves fully open Verify borated water volume Verify Nitrogen cover pressure Verify boron concentration Verify power removed from isolation valve TSTF-425 3.4.11.3 3.4.11.4 3.4.12 3.4.12.1 3.4.12.2 3.4.12.1 3.4.12.2 3.4.12.2 3.4.12.3 3.4.12.4 3.4.12.5 3.4.12.6 3.4.12.7 3.4.12.8 Attachment 2 Page 5 of 11 GINNA ----------------

3.4.12 3.4.12.1 3.4.12.2 3.4.12.2 3.4.12.3 ---------------

3.4.12.4 3.4.12.5 ---------------

3.4.12.6 ---------------

3.4.12.7 3.4.12.9 3.4.12.8 3.4.13 3.4.13 3.4.13.1 3.4.13.1 3.4.13.2 3.4.13.2 3.4.14 3.4.14 3.4.14.1 3.4.14.1 3.4.14.2 3.4.14.2 ---------------

3.4.14.3 ---------------

3.4.15 3.4.15 3.4.15.1 3.4.15.1 3.4.15.2 3.4.15.2 3.4.15.3 3.4.15.3 3.4.15.4 3.4.15.4 3.4.15.5 ---------------

3.4.16 3.4.16 3.4.16.1 3.4.16.1 3.4.16.2 3.4.16.2 3.4.16.3 3.4.16.3 3.4.17 ---------------

3.4.17.1 ---------------

3.4.19 ---------------

3.4.19.1 ---------------

3.5.1 3.5.1 3.5.1.1 3.5.1.1

3.5.1.2 3.5.1.2 3.5.1.3 3.5.1.3 3.5.1.4 3.5.1.4 3.5.1.5 3.5.1.5 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

ECCS -Operating Verify (listed) valves in proper position with power removed Verify valves in flow path in the proper position with power removed (Note 1) Verify breakers, for each valve listed in 3.5.2.1, in correct position Verify ECCS pipinQ full of water Verify ECCS automatic valves actuates to its proper position on an actual or simulated signal Verify ECCS pumps starts automatically on an actual or simulated signal Verify ECCS throttle valves (listed) in the correct position Visual inspection of ECCS train Verify locations susceptible to Qas accumulation are filled RWST Verify RWST borated water temperature Verify RWST borated water volume Verify RWST boron concentration Seal Injection Flow Verify manual seal injection valves adjusted to proper flow BIT Verify BIT borated water temperature Verify BIT borated water volume Verify BIT boron concentration Containment Air Locks Verify one door can be opened at a time Containment Isolation Valves I Boundaries Verify purQe valve [42 inch] closed Verify purae valve f8 inchl closed Verify manual isolation valves, blind flanges outside containment closed Verify isolation times Cycle each testable check valves throuQh one full cycle Leakrate purge valves with resilient seals Verify automatic valves actuate to their correct position on an actual or simulated sianal Cycle each testable check valves throuah one full cycle Verify purae valve is blocked to restrict flow Containment Pressure Verify containment pressure within limits Containment Temperature Verify containment averaQe temperature within limits Containment Spray and Cooling Systems I (CS,CRFC and NaOH System) Verify valves in the flow path in the correct position (Note 1) Operate containment cooling system minutes) TSTF-425 3.5.2 3.5.2.1 3.5.2.2 -------------

3.5.2.3 3.5.2.5 3.5.2.6 3.5.2.7 3.5.2.8 -------------

3.5.4 3.5.4.1 3.5.4.2 3.5.4.3 3.5.5 3.5.5.1 3.5.6 3.5.6.1 3.5.6.2 3.5.6.3 3.6.2 3.6.2.2 3.6.3 3.6.3.1 3.6.3.2 3.6.3.3 3.6.3.5 3.6.3.6 3.6.3.7 3.6.3.8 3.6.3.9 3.6.3.10 3.6.4A 3.6.4A.1 3.6.5A 3.6.5A.1 3.6.6A 3.6.6A.1 3.6.6A.2 Attachment 2 Page 6 of 11 GINNA 3.5.2 3.5.2.1 3.5.2.2 3.5.2.3 ----------------

3.5.2.5 3.5.2.6 ----------------

3.5.2.7 3.5.2.8 3.5.4 ---------------

3.5.4.1 3.5.4.2 --------------

3.6.2 3.6.2.2 3.6.3 --------------

3.6.3.1 3.6.3.2 --------------

3.6.3.6 ----------------------------

3.6.4 3.6.4.1 3.6.5A 3.6.5.1 3.6.6 3.6.6.2 3.6.6.4 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

Verify containment coolinQ train water flow Qpm) Verify containment spray valves actuate to their correct position on an actual or simulated signal Verify containment spray pumps starts on an actual or simulated signal Verify containment cooling train starts on an actual or simulated signal Spray Additive System Verify valves in the flow path in the correct position Verify spray tank solution volume Verify NaOH concentration Verify containment spray additive tank valves actuate to their correct position on an actual or simulated signal Verify spray additive flow from each solution flow path Verify CS locations susceptible to Qas accumulation are filled MSIV I (MSIV and Non-Return Check Valves) Verify MSIV actuate to its isolation position on an actual or simulated signal MFIVs and MFRVs, and Associated Bypass Valves Verify the isolation time of each MFIV, MFRV and associated bypass valve Atmosphere Dump (Relief) Valves (ADVs)(ARVs)

Verify once complete cycle of each ADV(ARV) Verify once complete cycle of each ADV (ARV) block valve AFW System Verify valves in the water and steam flow path in their correct position Verify each AFW automatic valve actuates to the isolation position on an actual or simulated signal Verify each AFW pump starts automatically on an actual or simulated signal Verify each SAFW train can be operated from control room Condensate Storage Tank (CST) Verify CST level Component Cooling Water System (CCW) Verify each CCW valve is in the correct position Verify each CCW valve in the flow path actuates to the correct position on an actual or simulated siQnal Verify each CCW pump starts automatically on an actual or simulated siQnal Service Water System (SWS) Verify screen house bay water level and temperatures Verify each SWS valve is in the correct position Verify each SWS valve in the flow path actuates to the correct position on an actual or simulated siQnal Attachment 2 Page 7 of 11 TSTF-425 GINNA 3.6.6A.3 3.6.6.5 3.6.6A.5 3.6.6.10 3.6.6A.6 3.6.6.11 3.6.6A.7 3.6.6.12 3.6.7 ------------

3.6.7.1 3.6.6.3 3.6.7.2 3.6.6.7 3.6.7.3 3.6.6.8 3.6.7.4 3.6.6.13 3.6.7.5 3.6.6.14 --------------

3.6.6.16 3.7.2 3.7.2 3.7.2.2 3.7.2.3 3.7.3 3.7.3 3.7.3.2 ----------------

3.7.4 3.7.4 3.7.4.1 3.7.4.1 3.7.4.2 3.7.4.2 3.7.5 3.7.5 3.7.5.1 3.7.5.1 3.7.5.3 3.7.5.5 3.7.5.4 3.7.5.6 ------------

3.7.5.7 3.7.6 3.7.6 3.7.6.1 3.7.6.1 3.7.7 3.7.7 3.7.7.1 3.7.7.1 3.7.7.2 --------------3.7.7.3 --------------3.7.8 3.7.8 -------------

3.7.8.1 3.7.8.1 3.7.8.2 3.7.8.2 3.7.8.4 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

Verify each SWS pump starts automatically on an actual or simulated siqnal Verify SW loop header cross-tie valves in correct position Ultimate Heat Sink (UHS) Verify water level in the UHS Verify average water temperature in the UHS Operate each coolinq tower fan (2!15 minutes) Verify cooling fan starts automatically on an actual or simulated siqnal Control Room Emergency Filtration System (CREFS) Operate each GREFS train {2!15 minutes) with the heaters on {2!15 minutes) Verify each GREF train actuates on an actual or simulated siqnal Verify each GREF train maintain a positive pressure Control Room Emergency Air Temperature Control System (CREATCS)

Verify the GREATGS removes the assume heat load Operate GREATS filtration train (2!15 minutes) Verify each GREATS train actuates on an actual or simulated signal Auxiliary Building Ventilation System Verify ABVS in operation Verify ABVS maintains negative pressure with respect to Aux. Bldg. ECCS PREACS Operate each PREAG for 2!1 O hours with heaters on or for 2!15 minutes for systems without heaters Verify each PREAG train actuates on an actual or simulated signal Verify PREAG can maintained pressure Verify each EGGS PREAG filter bypass damper closed FBACS Operate each FBAGS for 2!1 O hours with heaters on or for 2!15 minutes for systems without heaters Verify each FBAGS train actuates on an actual or simulated signal Verify FBAGS can maintained pressure Verify each FBAGS filter bypass damper closed PREACS Operate each PREAG for 2!1 O hours with heaters on or for 2!15 minutes for systems without heaters Verify each PREAG train actuates on an actual or simulated signal Verify PREAG can maintained pressure Verify each EGGS PREAG filter bypass damper closed Fuel Storage Pool Water Level Verify fuel storage pool water level (2!23 feet) Spent Fuel Pool Boron Concentration Verify spent fuel boron concentration within limits Secondary Specific Activity TSTF-425 3.7.8.3 ------------

3.7.9 3.7.9.1 3.7.9.2 3.7.9.3 3.7.9.4 3.7.10 3.7.10.1 3.7.10.3 3.7.10.4 3.7.11 3.7.11.1 Attachment 2 Page 8 of 11 GINNA 3.7.8.5 3.7.8.3 --------------

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3.7.15 3.7.11 3.7.15.1 3.7.11.1 3.7.16 3.7.12 3.7.16.1 3.7.12.1 3.7.18 3.7.14 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

Verify specific activity of Dose Equivalent 1-131 (:50.10) AC Sources -Operating Verify correct breaker alianment Verify each diesel starts from standby conditions Verify each diesel is synchronized and loaded 60 minutes) Verify each day tank contains proper fuel 220 aallons) Check and remove accumulated water Verify fuel oil transfer operation (from storaae tank to day tanks) Verify each diesel starts from standby conditions in proper time (:51 O sec) Verify transfer of AC power sources (Normal to Alternate)

Load rejection test (largest post-accident load) Verify diesel does not trip and voltage is maintained during and following the load rejection Verify diesel performs properly on an actual or simulated loss of offsite power sianal Verify on an actual or simulated ESF actuation each diesel auto starts from standby conditions Verify non critical trips are bypassed Verify each diesel operates for areater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Verify diesel starts and performs properly within 5 minutes of operatina for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months a maximum load Verify diesel synchronizes with offsite power while loaded with emergency loads Verify an actual or simulated ESF signal overrides a test sianal Verify interval between each sequenced load block Verify on an actual or simulated loss of offsite power in conjunction with an actual or simulated ESF sianal the diesel performs properly Verify when started simultaneously from standby conditions each diesel performs properly Diesel Fuel Oil, Lube Oil, and Starting Air Verify each fuel oil storage tank volume (aallons)

Verify lube oil inventory Verify diesel start receiver pressure Check and remove accumulated water DC Sources -Operating Verify battery terminal voltaae Verify battery charaer can recharae the battery Verify battery capacity Battery Parameters Verify battery float current Verify each pilot cell voltaae Verify connected batteries electrolyte level Verify averaqe electrolyte temperature (fifth cell of each battery) Attachment 2 Page 9 of 11 TSTF-425 GINNA 3.7.18.1 3.7.14.1 3.8.1 3.8.1 3.8.1.1 3.8.1.1 3.8.1.2 3.8.1.2 3.8.1.3 3.8.1.3 3.8.1.4 3.8.1.4 3.8.1.5 --------------

3.8.1.6 3.8.1.5 3.8.1.7 3.8.1.2 3.8.1.8 3.8.1.6 3.8.1.9 3.8.1.7 3.8.1.10 3.8.1.7 3.8.1.11 3.8.1.9 3.8.1.12 3.8.1.9 3.8.1.13 3.8.1.8 3.8.1.14 ----------

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3.8.3 3.8.3 3.8.3.1 3.8.3.1 3.8.3.2 --------------3.8.3.4 --------------

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3.8.4 3.8.4 3.8.4.1 3.8.4.1 3.8.4.2 ----------

3.8.4.3 3.8.4.2 3.8.4.3 3.8.6 3.8.6 3.8.6.1 ---------------3.8.6.2 -------------

3.8.6.3 3.8.6.1 -----------

--3.8.6.5 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Technical Specification Section Title/Surveillance Description*

Verify specific gravity of pilot cell Verify specific gravity of each connected cell Verify each pilot cell temperature Verify connected battery cell voltage Verify battery capacity Inverters

-Operating Verify inverter voltage and alignment to AC buses AC Instrument Bus Sources -MODES 1, 2, 3 and 4 Verify correct static switch alignment Verify correct Class 1 E CVT alignment Inverters

-Shutdown Verify inverter voltage and alignment to AC buses AC Instrument Bus Sources -MODES 5 and 6 Verify correct static switch alignment Verify correct Class 1 E CVT alignmnet Distribution Systems -Operating Verify correct breaker alignment and voltage of required buses Distribution Systems -MODES 1, 2, 3 and 4 Verify correct breaker alignment and voltage of required buses Distribution Systems -Shutdown Verify correct breaker alignment and voltage of required buses Distribution Systems -MODES 5 and 6 Verify correct breaker alignment and voltage of required buses Boron Concentration Verify boron concentration within the COLR Unborated Water Source Isolation Valves Verify each valve that isolates unborated water source is closed Nuclear Instrumentation Channel Check Channel Calibration Containment Penetrations Verify containment penetration in required status Verify purge and exhaust valves isolate on an actual or simulated signal RHR and Coolant Circulation

-High Water Level (>23 Ft) Verify one RHR loop in operation circulating reactor coolant Verify RHR locations susceptible to gas accumulation are filled RHR and Coolant Circulation

-Low Water Level (< 23 Ft) Verify one RHR loop in operation Verify correct breaker alignment and power to operating RHR pump Verify RHR locations susceptible to gas accumulation are filled Refueling Cavity Water Level Verify refueling cavity water level above flange Attachment 2 Page 10 of 11 TSTF-425 GINNA -------------

3.8.6.3 --------------

3.8.6.6 3.8.6.4 3.8.6.4 3.8.6.5 3.8.6.2 3.8.6.6 3.8.4.3 3.8.7 -------------

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3.9.3 3.9.2 3.9.3.1 3.9.2.1 3.9.3.2 3.9.2.2 3.9.4 3.9.3 3.9.4.1 3.9.3.1 3.9.4.2 3.9.3.2 3.9.5 3.9.4 3.9.5.1 3.9.4.1

3.9.4.2 3.9.6 3.9.5 3.9.6.1 3.9.5.1 3.9.6.2 3.9.5.2 ------------

3.9.5.3 3.9.7 3.9.6 3.9.7.1 3.9.6.1 Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 Attachment 2 Page 11 of 11

The Technical Specification Section Title/Surveillance Description portion of this attachment is a summary description of the referenced TSTF-425 (NUREG-1431)/Ginna TS Surveillances which is provided for information purposes only and is not intended to be a verbatim description of the TS Surveillances.

Note 1 : Existing surveillances. Only surveillance text was modified as a result of approved NRG Amendment.

ATTACHMENT 3 Supplement to License Amendment Request R. E. Ginna Nuclear Power Plant Docket No. 50-244 Application for Technical Specification Change Regarding Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Marked-up Technical Specification Pages as Modified by Reference 3

CONDITION REQUIRED ACTION 8. One RHR loop ------------------

-NOTE -inoperable. Required Action 8.1 is not AND applicable if all RCS and RHR loops are inoperable Two RCS loops and Condition C is entered. ------------------

inoperable. 8.1 Be in MODE 5. C. All RCS and RHR loops C.1 Suspend operations that inoperable.

would cause introduction of coolant into the RCS with OR boron concentration less than required to meet the No RCS or RHR loop in SOM of LCO 3.1.1. operation.

AND C.2 Initiate action to restore one loop to OPERABLE status and operation. SURVEILLANCE REQUIREMENTS SR 3.4.6.1 SR 3.4.6.2 SR 3.4.6.3 SR 3.4.6.4 SURVEILLANCE Verify one RHR or RCS loop is in operation.

Verify SG secondary side water level is 16% for each required RCS loop. Verify correct breaker alignment and indicated power are available to the required pump that is not in operation. --------------------------NOTE---------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4. Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water. R.E. Ginna Nuclear Power Plant 3.4.6-2 RCS Loops-MODE 4 3.4.6 COMPLETION TIME 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Immediately Immediately FREQUENCY

'INSERT 1 INSERT 1 Amendment 118 RCS Loops -MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore a Immediately inoperable.

second RHR loop to OPERABLE status. AND OR Both SGs secondary side water levels not within A.2 Initiate action to restore Immediately limits. required SG secondary side water levels to within limits. B. Both RHR loops B.1 Suspend operations that Immediately inoperable.

would cause introduction of coolant into the RCS with OR boron concentration less than required to meet the No RHR loop in SOM of LCO 3.1.1. operation. AND B.2 Initiate action to restore one Immediately RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation.

12 I SR 3.4.7.2 Verify SG secondary side water level 16% in the 12 heurs SR 3.4.7.3 SR 3.4.7.4 required SG. .... ,-------J:INSERT 1 I Verify correct breaker alignment and indicated power are available to the required RHR pump that is not in operation. 7 eay%-----1llNSERT 1 I Verify required RHR loop locations susceptible to gas 31 accumulation are sufficiently filled with water. "-------JllNSERT 1 I R.E. Ginna Nuclear Power Plant 3.4.7-2 Amendment 118 CONDITION

8. Both RHR loops inoperable.

No RHR loop in operation.

8.1 AND 8.2 SURVEILLANCE REQUIREMENTS RCS Loops -MODE 5, Loops Not Filled 3.4.8 REQUIRED ACTION COMPLETION TIME Suspend operations that Immediately would cause introduction of coolant into the RCS with boron concentration less than required to meet the SOM of LCO 3.1.1. Initiate action to restore one Immediately RHR loop to OPERABLE status and operation. SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 1 I SR 3.4.8.2 Verify correct breaker alignment and indicated power ....,

SR 3.4.8.3 are available to the RHR pump that is not in operation. Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water. R.E. Ginna Nuclear Power Plant 3.4.8-2 1 31 days 1 1NSERT 1 I Amendment

!.18 .

ECCS -MODES 1, 2, and 3 3.5.2 SURVEILLANCE REQUIREMENTS SR 3.5.2.1 SR 3.5.2.2 SURVEILLANCE Verify the following valves are in the listed position.

Number Position Function 825A Open RWST Suction to SI Pumps 825B Open RWST Suction to SI Pumps 826A Closed BAST Suction to SI Pumps 826B Closed BAST Suction to SI Pumps 826C Closed BAST Suction to SI Pumps 8260 Closed BAST Suction to SI Pumps 851A Open Sump B to RHR Pumps 851B Open Sump B to RHR Pumps 856 Open RWST Suction to RHR Pumps 878A Closed SI Injection to RCS Hot Leg 878B Open SI Injection to RCS Cold Leg 878C Closed SI Injection to RCS Hot Leg 8780 Open SI Injection to RCS Cold Leg 896A Open RWST Suction to SI and Containment Spray 896B Open RWST Suction to SI and Containment Spray ---------------------N 0 TE---------------------------------------

N ot required to be met for system vent flow paths opened under administrative control. Verify each ECCS manual, power operated , and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

FREQUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INSERT 1 R.E. Ginna Nuclear Power Plant 3.5.2-2 Amendment 118 SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7 SR 3.5.2.8 ECCS -MODES 1, 2, and 3 3.5.2 SURVEILLANCE FREQUENCY Verify each breaker or key switch, as applicable , for each 31 aey valve listed in SR 3.5.2.1, is in the correct position.

Verify each ECCS pump's developed head at the test flow In accordance point is greater than or equal to the required developed with the head. lnservice Testing Program Verify each ECCS automatic valve in the flow path that is 24"'\ llN not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal. SERT 1 Verify each ECCS pump starts automatically on an actual 24 ffie or simulated actuation signal.

Verify, by visual inspection , each RHR containment sump suction inlet is not restricted by debris and the containment sump screen shows no evidence of structural distress or abnormal corrosion. NSERT 1 Verify ECCS locations susceptible to gas accumulation 31 ea are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.5.2-3 Amendment 118 CS, CRFC, and NaOH Systems 3.6.6 CONDITION REQUIRED ACTION F. Two CS trains inoperable.

F.1 Enter LCO 3.0.3. Three or more CRFC units inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.6.1 Perform SR 3.5.2.1 and SR 3.5.2.3 for valves 896A and 8968. SR 3.6.6.2 ---------------------NOTE------------------------

Not required to be met for system vent flow paths opened under administrative control. -------------------------------------------------------

Verify each CS manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position. SR 3.6.6.3 Verify each NaOH System manual, power operated, and automatic valve in the flow path that is not locked, sealed , or otherwise secured in position is in the correct position. SR 3.6.6.4 Operate each CRFC unit for 2 15 minutes. SR 3.6.6.5 Verify cooling water flow through each CRFC unit. SR 3.6.6.6 Verify each CS pump's developed head at the flow test point is greater than or equal to the required developed head. SR 3.6.6.7 Verify NaOH System solution volume is 2 3000 gal. SR 3.6.6.8 Verify NaOH System tank NaOH solution concentration is 2 30% and 35% by weight. SR 3.6.6.9 Perform required CRFC unit testing in accordance with the VFTP. R.E. Ginna Nuclear Power Plant 3.6.6-2 COMPLETION TIME Immediately FREQUENCY In accordance with applicable SRs. INSER T1 .... .. -'-**---INS ERT 1 I In accordance with the lnservice Testing Program In accordance with the VFTP -!INSERT 1 I INSERT 1 ---illNSERT NSERT 1 Amendment 118 SR 3.6.6.10 SR 3.6.6.11 SR 3.6.6.12 SR 3.6.6.13 SR 3.6.6.14 SR 3.6.6.15 SR 3.6.6.16 CS, CRFC, and NaOH Systems 3.6.6 SURVEILLANCE FREQUENCY Verify each automatic CS valve in the flow path that is not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal. :INSERT 1 I Verify each CS pump starts automatically on an actual 24 R'leAtl=ls or simulated actuation signal. Verify each CRFC unit starts automatically on an actual or simulated actuation signal. INSERT 1 I Verify each automatic NaOH System valve in the flow 2!4 R'lefltl=ls path that is not locked, sealed, or otherwise secured in position actuates to the correct position on an INSERT 1 I actual or simulated actuation signal. Verify spray additive flow through each eductor path. "' -----,_ "'---Verify each spray nozzle is unobstructed. Following 1 I maintenance which could result in nozzle blockage Verify CS locations susceptible to gas accumulation

">A *--are sufficiently filled with water.

1 I R.E. Ginna Nuclear Power Plant 3.6.6-3 Amendment 118

3.9.4 CONDITION

REQUIRED ACTION COMPLETION TIME A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SR 3.9.4.1 SURVEILLANCE Verify one RHR loop is in operation and circulating reactor coolant. R.E. Ginna Nuclear Power Plant 3.9.4-2 FREQUENCY Amendment 118 RHR and Coolant Circulation

-Water Level < 23 Ft 3.9.5 SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 SR 3.9.5.3 SURVEILLANCE Verify one RHR loop is in operation and circulating reactor coolant. Verify correct breaker alignment and indicated power available to the required RHR pump that is not in operation.

Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water. R.E. Ginna Nuclear Power Plant 3.9.5-2 FREQUENCY 12 t'leurs ......

1 INSERT 1 INSERT 1 Amendment 118 ATTACHMENT 4 Supplement to License Amendment Request R. E. Ginna Nuclear Power Plant Docket No. 50-244 Application for Technical Specification Change Regarding Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Marked up Technical Specification Bases as Modified by Reference 3

SURVEILLANCE REQUIREMENTS SR 3.4.6.1 RCS Loops -MODE 4 8 3.4.6 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one RCS or RHR loop is in operation. Verification includes flow rate, temperature , or pump status monitoring, which help ensure that forced flow is providing heat removal. Use of control board indication for these parameters is an acceptable verification. 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 a\*ailable to the operator in the control room to monitor RCS and RHR loop perforrnaneei}

!INSERT 3 I SR 3.4.6.2 This SR requires verification of SG OPERABILITY.

SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is z 16%. If the SG secondary side narrow range water level is< 16%, the tubes may become uncovered and the associated loop may not be capable of providing the heat sink necessary for removal of decay heat. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is considered adequate in view of other indications available in the control room to alert the operato r to the loss of :: !INSERT 31 Verification that the required pump is OPERABLE ensures that an additional RCS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.

Verification is performed by verifying proper breaker alignment and power available to the required pump that is not in operation. The Frequency of 7 days is considered reasonable in view of other administrative controls available aAd has beeA shewA le be aeeeptable by REFERENCES

1. UFSAR, Section 14.6.1.2.6. RE. Ginna Nuclear Power Plant B 3.4.6-5 Revision 61 SURVEILLANCE REQUIREMENTS SR 3.4.7.1 RCS Loops -MODE 5, Loops Filled B 3.4.7 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one RHR loop is in operation.

Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal. Use of control board indication for these parameters is an acceptable verification.

The Frequeney of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient considering other indieations and alarrns available to the operator in the control roorn to monitor RHR loop performanee. SR3.4.7.2 This SR requires verification of SG OPERABILITY.

Verifying that at least one SG is OPERABLE by ensuring its secondary side narrow range water level is 16% ensures an alternate decay heat removal method in the event that the second RHR loop is not OPERABLE.

If both RHR loops are OPERABLE, this Surveillance is not needed. T he 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is considered adequate in view of other indi e ations available in the eontrol roorn to alert the operator to the loss of SC SR 3.4.7.3 !INSERT 3 Verification that a second RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed , to maintain decay heat removal and reactor coolant circulation.

Verification is performed by verifying proper breaker alignment and power available to the standby RHR pump. If secondary side water level 16% in at least one SG , this Surveillance is not needed. The F requency of 7 days is considered reasonable in view of othe r administrative controls available end hes shewA te Be aeeeptaBle By eperatiAg e*perieAeet

!INSERT 3 I l1NSERTBI REFERENCES

1. UFSAR, Section 14.6.1.2.6 2. NRC Information Notice 95-35 RE. Ginna Nuclear Power Plant B 3.4.7-5 Revision 61 SURVEILLANCE REQUIREMENTS SR 3.4.8.1 RCS Loops -MODE 5, Loops Not Filled B 3.4.8 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one RHR loop is in operation. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal. 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 alarrns available to the operator in the control room to rnonitor RHR loop perforrnanee.11\ SR3.4.8.2 Verification that a second RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the standby pump. The Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shmun to be aeee"1able by epeFS!iRg e*perieReeiJ'

!INSERT 3 I REFERENCES

1. None. RE. Ginna Nuclear Power Plant B 3.4.8-4 Revision 61 SR 3.5.2.6 See SR 3.5.2.5 SR 3.5.2.7 ECCS -MODES 1, 2, and 3 B 3.5.2 Periodic inspections of the containment sump suction inlet to the RHR System ensure that it is unrestricted and stays in proper operating condition. The 24 A'tonth Frequency is bases on the neea to perform this Surveillance unaer the eonaitions that apply auring a plant outage, ana the neea to have access to the location. This Frequency has been feuna to be sufficient to aeteet abnormal aegraaation ana is confirmea by operating experience

.,t. REFERENCES

1. Letter from R. A. Purple, NRC, to L. D. White, RG&E,

Subject:

"Issuance of Amendment 7 to Provisional Operating License No. DPR-18," dated May 14, 1975. 2. Branch Technical Position (BTP) ICSB-18, "Application of the Single Failure Criterion to Manually-Controlled Electrically Operated Valves." 3. Letter from A. R. Johnson, NRC, to R. C. Mecredy, RG&E,

Subject:

"Issuance of Amendment No. 42 to Facility Operating License No. DPR-18, R. E. Ginna Nuclear PONer Plant (TAC No. 79829)," dated June 3, 1991.

4. Letter from D. M. Crutchfield, NRC, to J. E. Maier , RG&E,

Subject:

"SEP Topic Vl-7.B: ESF Switchover from Injection to Recirculation Mode, Automatic ECCS Realignment, Ginna," dated December 31, 1981. 5. NUREG-0821. 6. UFSAR, Section 6.3. 7. Not Used 8. Atomic Industrial Forum (AIF) GDC 44, Issued for comment July 10, 1967. 9. 10 CFR 50.46. 10. UFSAR, Section 15.6. 11. UFSAR, Section 6.2. R.E. Ginna Nuclear Power Plant B 3.5.2-13 Revision 58 CS, CRFC and NaOH Systems B 3.6.6 Surveillances when performed at the 24 rnonth Frequency. Therefore, the Frequency was concluded to ec ecccptaelc frorn a reliability See SR 3.6.6.10 SR 3.6.6.12 This SR requires verification that each CRFC unit, and the charcoal filter train associated with the A and C units, actuates upon receipt of an actual or simulated safety injection signal. The 24 month Frequency is eased on engineering judgrncnt end hes seen sho'o'm to ec eecepteele through operating cMpericnec.

See SR 3.S.S.10 and SR 3.S.S.11, aeovc, for of the easis for the 24 rnonth Frcqucney. This SR provides verification that each automatic valve in the NaOH System flow path that is not locked, scaled, or otherwise secured in position (836A and 8368) actuates to its correct position upon receipt of an actual or simulated actuation of a containment Hi-Hi pressure signal. The 24 rnonth frequency is eased on engineering judgement and has seen shown to ec acccptaelc through operating cMpcricncc.

Sec SR 3.S.S.1 O end SR 3.S.S.11, eeovc, for further discussion of the eesis for the 24 month Frequency.

'1' .---------.

SR3.6.6.14 To ensure that the correct pH level is established in the borated water solution provided by the CS System, flow through the cductor is verified onee every 6 years. This SR in conjunction with SR 3.6.6.13 provides that NaOH will be added into the flow path upon CS initiation.

A minimum flow of 20 gpm through the cductor must be established as assumed in the accident analyses. A flow path must also be verified from the NaOH tank to the cductors.

Due to the passive nature of the spray additive flo*.v controls, the 6 year Frequency is sufficient to identify degradation that may effect flow injcetion. With the CS inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.

As an alternative, a visual inspection (e.g. boroscope) of the nozzles or piping could be utilized in lieu of an air or smoke test if a visual inspection is determined to provide an equivalent or a more effective post-maintenance test. A visual inspection may be more effective if the potential for material intrusion is localized and the affected area is accessible.

This SR ensures that each spray nozzle is unobstructed and provides assurance that spray coverage of the during an accident is not degraded.

Due to the passive RE. Ginna Nuclear Power Plant B 3.6.6-11 Revision 72 SURVEILLANCE REQUIREMENTS RHR and Coolant Circulation

-Water Level z. 23 Ft B 3.9.4 If RHR loop requirements are not met, all containment penetrations providing direct access from the containment atmosphere to the outside atmosphere must be closed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . With the RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere.

Closing containment penetrations that are open to the outside atmosphere ensures dose limits are not exceeded.

The Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is reasonable, based on the low probability of the coolant boiling in that time. SR 3.9.4.1 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one RHR loop is in operation and circulating reactor coolant. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providiflg decay heat removal capability and mixing of the borated coolant to prevent thermal and boron stratification in the core. Freeiuency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is su#icient considering other indications and alarms available to the 019erator in the control room to monitor RHR 10019 19erformance.f1\ REFERENCES

1. UFSAR, Section 5.4.5. 2. UFSAR, Section 15.4.4.2.

RE. Ginna Nuclear Power Plant B 3.9.4-4 Revision 61 SURVEILLANCE REQUIREMENTS INSERTG REFERENCES SR 3.9.5.1 RHR and Coolant Circulation

-Water Level < 23 Ft B 3.9.5 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one RHR loop is in operation and circulating reactor coolant. Verification includes flow rate , temperature, or pump status monitoring, which help ensure that forced flow is providing decay heat removal capability and mixing of the borated coolant to prevent thermal and boron stratification in the core. FFCquency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient consielering other inelications anel alarffis available to the operator in the control rooffi to ffionitor RHR loop Verification that a second RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.

Verification is performed by verifying proper breaker alignment and power available to the standby pump. The Frequency of 7 elays is consielereel reasonable in view of other aelA'linistrative controls available anel has been shown to be acceptable by operating experience. 1. UFSAR , Section 5.4.5. 2. UFSAR , Section 15.4.4. R.E. Ginna Nuclear Power Plant B 3.9.5-4 Revision 61 ATTACHMENT 5 Supplement to License Amendment Request R. E. Ginna Nuclear Power Plant Docket No. 50-244 Application for Technical Specification Change Regarding Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Proposed Technical Specification Bases Description per Reference 3

Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 INSERT A SR 3.4.6.4 Attachment 5 Page 1 of 7 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the required RHR loop(s) and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel. Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations.

The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration.

Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations.

If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. RHR System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location.

Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may beverified by monitoring a representative sub-set of susceptible locations.

Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location.

Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY.

The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assure system OPERABILITY during the Surveillance interval.

This SR is modified by a Note that states the SR is not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4. In a rapid shutdown, there may be insufficient time to verify all susceptible locations prior to entering MODE 4. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Surveillance Frequency may vary by location susceptible to gas accumulation.

Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 INSERT B SR 3.4.7.4 Attachment 5 Page 2 of 7 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the required RHR loop(s) and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel. Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations.

The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration.

Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations.

If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. RHR System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location.

Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations.

Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location.

Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY.

The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assure system OPERABILITY during the Surveillance interval.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Surveillance Frequency may vary by location susceptible to gas accumulation.

Supplement to License Amendment Request Adoption of TSTF-425, Rev. 3 October 2, 2015 Docket No. 50-244 INSERTC SR 3.4.8.3 Attachment 5 Page 3 of 7 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR loops and may also prevent water hammer, pump cavitation, and pumping of non-condensible gas into the reactor vessel. Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations.