Text

Issuance of Amendment Nos. 132 and 36 Regarding the Adoption of Technical Specifications Task Force Traveler TSTF-425, Revision 3
	ML20028F733
Person / Time
Site:	Watts Bar
Issue date:	02/28/2020
From:	Michael Wentzel; Plant Licensing Branch II
To:	Jim Barstow; Tennessee Valley Authority
	Green K
References
	EPID L-2018-LLA-0279
	Download: ML20028F733 (280)
	v • d • e

February 28, 2020 Mr. James Barstow Vice President, Nuclear Regulatory Affairs and Support Services Tennessee Valley Authority 1101 Market Street, LP 4A-C Chattanooga, TN 37402-2801

SUBJECT:

WATTS BAR NUCLEAR PLANT, UNITS 1 AND 2 - ISSUANCE OF AMENDMENT NOS. 132 AND 36 REGARDING THE ADOPTION OF TECHNICAL SPECIFICATIONS TASK FORCE TRAVELER TSTF-425, REVISION 3 (EPID L-2018-LLA-0279)

Dear Mr. Barstow:

The U.S. Nuclear Regulatory Commission (NRC or the Commission) has issued the enclosed Amendment No. 132 to Facility Operating License No. NPF-90 and Amendment No. 36 to Facility Operating License No. NPF-96 for the Watts Bar Nuclear Plant, Units 1 and 2, respectively. These amendments are in response to your application dated October 12, 2018; as supplemented by letters dated May 7, June 6, and August 29, 2019; and January 17, 2020.

The amendments revise certain technical specifications (TSs) by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies. The changes are consistent with Technical Specification Task Force (TSTF) Traveler TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - Risk Informed Technical Specification Task Force (RITSTF)

Initiative 5b. The amendments also revise TS Section 5.0, Administrative Controls, to add the new Surveillance Frequency Control Program. A copy of our related safety evaluation is also enclosed. A notice of issuance will be included in the Commissions biweekly Federal Register notice.

Additionally, on October 22, 2015, the NRC issued the initial operating license for Watts Bar Nuclear Plant, Unit 2 (Agencywide Documents Access and Management System Accession No. ML15251A587). As issued, the Completion Time for Required Action C.1 of TS 3.3.8, Auxiliary Building Gas Treatment System (ABGTS) Actuation Instrumentation, states, hours, with no numerical value indicated. Previous draft versions of the TSs submitted prior to license issuance indicate that the Completion Time for Required Action C.1 should state, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (see, e.g., Agencywide Documents Access Management System Accession No. ML15187A461). The NRC staff has determined that the numerical value for the Completion Time was inadvertently omitted during license issuance. As such, the NRC staff has corrected the Completion Time for Required Action C.1 on the revised Unit 2 TS Page 3.3-64 that is being issued for this current amendment to state, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . The NRC staff concludes that the correction is entirely editorial

J. Barstow in nature and does not change the staffs previous conclusions documented in its safety evaluation for license issuance, as supplemented.

Sincerely,

/RA/

Michael J. Wentzel, Project Manager Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-390 and 50-391

Enclosures:

1. Amendment No. 132 to NPF-90

2. Amendment No. 36 to NPF-96

3. Safety Evaluation cc: Listserv

TENNESSEE VALLEY AUTHORITY DOCKET NO. 50-390 WATTS BAR NUCLEAR PLANT, UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 132 License No. NPF-90

1. The U.S. Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Tennessee Valley Authority (TVA, the licensee) dated October 12, 2018; as supplemented by letters dated May 7, June 6, and August 29, 2019; and January 17, 2020; complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-90 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A as revised through Amendment No. 132 and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. TVA shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 60 days, except for the changes to Technical Specification Surveillance Requirements 3.7.18.1 and 3.9.9.1. The changes to Technical Specification Surveillance Requirements 3.7.18.1 and 3.9.9.1 shall be implemented prior to startup from the outage where any number of tritium producing burnable absorber rods is inserted in the Watts Bar Nuclear Plant, Unit 2 reactor core, not to exceed December 31, 2022.

FOR THE NUCLEAR REGULATORY COMMISSION

/RA/ G. Edward Miller for Undine Shoop, Chief Plant Licensing Branch II-2 Division of operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Operating License and Technical Specifications Date of Issuance: February 28, 2020

ATTACHMENT TO AMENDMENT NO. 132 WATTS BAR NUCLEAR PLANT, UNIT 1 FACILITY OPERATING LICENSE NO. NPF-90 DOCKET NO. 50-390 Replace page 3 of Facility Operating License No. NPF-90 with the attached revised page 3.

Replace the following pages of the Appendix A Technical Specifications with the attached pages. The revised pages are identified by amendment number and contain vertical lines indicating the area of change.

Remove Insert Remove Insert 3.1-1 3.1-1 3.4-6 3.4-6 3.1-2 3.1-2 3.4-7 3.4-7 3.1-4 3.1-4 3.4-9 3.4-9 3.1-10 3.1-10 3.4-10 3.4-10 3.1-13 3.1-13 3.4-13 3.4-13 3.1-16 3.1-16 3.4-15 3.4-15 3.1-22 3.1-22 3.4-17 3.4-17 3.1-24 3.1-24 3.4-19 3.4-19 3.2-3 3.2-3 3.4-24 3.4-24 3.2-5 3.2-5 3.4-28 3.4-28 3.2-8 3.2-8 3.4-29 3.4-29 3.2-9 3.2-9 3.4-31 3.4-31 3.2-12 3.2-12 3.4-34 3.4-34 3.3-10 3.3-10 3.4-38 3.4-38 3.3-11 3.3-11 3.4-40 3.4-40 3.3-12 3.3-12 3.4-41 3.4-41 3.3-13 3.3-13 3.5-2 3.5-2 3.3-14 3.3-14 3.5-3 3.5-3 3.3-31 3.3-31 3.5-5 3.5-5 3.3-32 3.3-32 3.5-6 3.5-6 3.3-33 3.3-33 3.5-10 3.5-10 3.3-43 3.3-43 3.5-12 3.5-12 3.3-47 3.3-47 3.6-7 3.6-7 3.3-50 3.3-50 3.6-12 3.6-12

-- 3.3-50a 3.6-13 3.6-13 3.3-54 3.3-54 3.6-15 3.6-15

-- 3.3-54a 3.6-17 3.6-17 3.3-59 3.3-59 3.6-19 3.6-19 3.3-62 3.3-62 3.6-23 3.6-23 3.4-2 3.4-2 3.6-24 3.6-24 3.4-4 3.4-4 3.6-25 3.6-25

Remove Insert Remove Insert 3.6-26 3.6-26 3.7-38 3.7-38 3.6-27 3.6-27 3.7-40 3.7-40 3.6-28 3.6-28 3.8-6 3.8-6 3.6-29 3.6-29 3.8-7 3.8-7 3.6-30 3.6-30 3.8-8 3.8-8 3.6-32 3.6-32 3.8-9 3.8-9 3.6-33 3.6-33 3.8-10 3.8-10 3.6-34 3.6-34 3.8-11 3.8-11 3.6-34a 3.6-34a 3.8-12 3.8-12 3.6-36 3.6-36 3.8-13 3.8-13 3.6-37 3.6-37 3.8-14 3.8-14 3.6-39 3.6-39 3.8-15 3.8-15 3.6-41 3.6-41 3.8-16 3.8-16 3.7-6 3.7-6 3.8-22 3.8-22 3.7-8 3.7-8 3.8-23 3.8-23 3.7-10 3.7-10 3.8-26 3.8-26 3.7-13 3.7-13 3.8-27 3.8-27 3.7-14 3.7-14 3.8-35 3.8-35 3.7-16 3.7-16 3.8-36 3.8-36 3.7-18 3.7-18 3.8-38 3.8-38 3.7-20 3.7-20 3.8-40 3.8-40 3.7-20a 3.7-20a 3.8-42a 3.8-42a 3.7-21 3.7-21 3.8-44 3.8-44 3.7-22 3.7-22 3.9-1 3.9-1 3.7-23 3.7-23 3.9-3 3.9-3 3.7-24 3.7-24 3.9-5 3.9-5 3.7-26 3.7-26 3.9-9 3.9-9 3.7-28 3.7-28 3.9-11 3.9-11 3.7-29 3.7-29 3.9-13 3.9-13 3.7-30 3.7-30 3.9-16 3.9-16 3.7-35 3.7-35 5.025c 5.025c

(4) TVA, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use in amounts as required, any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis, instrument calibration, or other activity associated with radioactive apparatus or components; and (5) TVA, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This license shall be deemed to contain and is subject to the conditions specified in the Commissions regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect, and is subject to the additional conditions specified or incorporated below.

(1) Maximum Power Level TVA is authorized to operate the facility at reactor core power levels not in excess of 3459 megawatts thermal.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A as revised through Amendment No. 132 and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. TVA shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) Safety Parameter Display System (SPDS) (Section 18.2 of SER Supplements 5 and 15)

Prior to startup following the first refueling outage, TVA shall accomplish the necessary activities, provide acceptable responses, and implement all proposed corrective actions related to having the Watts Bar Unit 1 SPDS operational.

(4) Vehicle Bomb Control Program (Section 13.6.9 of SSER 20)

During the period of the exemption granted in paragraph 2.D.(3) of this license, in implementing the power ascension phase of the approved initial test program, TVA shall not exceed 50% power until the requirements of 10 CFR 73.55(c)(7) and (8) are fully implemented. TVA shall submit a letter under oath or affirmation when the requirements of 73.55(c)(7) and (8) have been fully implemented.

Facility License No. NPF-90 Amendment No. 132

SOM - Tavg > 200°F 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)-Tavg > 200°F LCO 3.1.1 SOM shall be.:::. 1.6% i1k/k.

APPLICABILITY: MODE 2 with kett < 1.0, MODES 3 and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SOM not within limit. A.1 Initiate boration to restore SOM 15 minutes to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SOM is .:::. 1.6% i1k/k. In accordance with the Surveillance Frequency Control Program Watts Bar Unit 1 3.1-1 Amendment 55, 132

SOM - T avg ::;; 200°F 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 SHUTDOWN MARGIN (SOM) - Tavg ::;; 200°F LCO 3.1.2 The SOM shall be :?: 1.0% Lik/k.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SOM not within limit. A.1 Initiate boration to restore SOM 15 minutes to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify SOM is:?: 1.0% Lik/k. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.1-2 Amendment 55, 132

Core Reactivity 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 -----------------------------NOTE-----------------------

The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.

Verify measured core reactivity is within +/- 1% ~k/k of Once prior to predicted values. entering MODE 1 after initial fuel loading and each refueling AND

NOTE-------

Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.1-4 Amendment 132

Rod Group Alignment Limits 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. More than one rod not within D.1.1 Verify SDM is within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months alignment limit. specified in the COLR.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months D.1.2 Initiate boration to restore required SDM to within limit.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months D.2 Be in MODE 3.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 -----------------------NOTES---------------------------

1. Not required to be performed for rods associated with inoperable rod position indicator or demand position indicator.

2. Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify position of individual rods within alignment limit. In accordance with the Surveillance Frequency Control Program Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod position deviation monitor is inoperable SR 3.1.5.2 Verify rod freedom of movement (tripability) by In accordance with moving each rod not fully inserted in the core the Surveillance

,

10 steps in either direction. Frequency Control Program (continued)

Watt.s Bar-Unit 1 3.1-10 Amendment 120, 132

Shutdown Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more shutdown B.1.1 Verify SDM is within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months banks not within limits for specified in the COLR.

reasons other than Condition A. OR B.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND B.2 Restore shutdown banks to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within limits.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NO TE---------------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

SR 3.1.6.1 Verify each shutdown bank is within the limits insertion limits In accordance with specified in the COLR. the Surveillance Frequency Control Program '

WattsBar-Unit1 3.1-13 Amendment 120, 132

Control Bank Insertion Limits 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify estimated critical control bank position is within Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior the limits specified in the COLR. to achieving criticality SR 3.1.7.2 -------------------NOTE---------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify each control bank insertion is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod insertion limit monitor is inoperable SR 3.1.7.3 -----------------------NOTE---------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify sequence and overlap limits specified in the In accordance with COLR are met for control banks not fully withdrawn from the Surveillance the core. Frequency Control Program Watts Bar-Unit 1 3.1-16 Amendment 120, 132

PHYSICS TESTS Exceptions - MODE 1 3.1.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Verify THERMAL POWER is:,; 85% RTP. In accordance with the Surveillance Frequency Control Program SR 3.1.9.2 Verify Power Range Neutron Flux-High trip setpoints Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months prior are :,; 10% above the PHYSICS TESTS power level, to initiation of and :,; 90% RTP. PHYSICS TESTS SR 3.1.9.3 Perform SR 3.2.1.1 and SR 3.2.2.1. In accordance with the Surveillance Frequency Control Program SR 3.1.9.4 Verify SOM is ~ 1.6% ~k/k. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.1-22 Amendment 132

PHYSICS TESTS EXCEPTIONS - MODE 2 3.1.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop average C.1 Restore RCS lowest loop 15 minutes temperature not within limit. average temperature to within limit.

D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.10.1 Perform a CHANNEL OPERATIONAL TEST on power range Prior to initiation of and intermediate range channels per SR 3.3.1.7, SR 3.3.1.8, PHYSICS TESTS and Table 3.3.1-1.

SR 3.1.10.2 Verify the RCS lowest loop average temperature is ;;:: 541 °F. In accordance with the Surveillance Frequency Control Program SR 3.1.10.3 Verify SOM is ;;:: 1.6% ilk/k. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.1-24 Amendment 28, 132

Fo(Z) 3.2.1 SURVEILLANCE REQUIREMENTS

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

During power escalation at the beginning of each cycle, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained.

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify F0 c(Z) is within limit. Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by

~ 10% RTP, the THERMAL POWER at which F0 c(Z) was last verified In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.2-3 Amendment 132

Fo(Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 Once within 12 (continued) hours after achieving equilibrium conditions after exceeding, by

~ 10% RTP, the THERMAL POWER at which F0 w(Z) was last verified In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.2-5 Amendment 132

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify FN~H is within limits specified in the COLR. Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.2-8 Amendment 132

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)

LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.

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

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.

APPLICABILITY: MODE 1 with THERMAL POWER~ 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL POWER to 30 minutes

< 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore In accordance with channel. the Surveillance Frequency Control Program Once within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter with the AFD monitor alarm inoperable Watts Bar-Unit 1 3.2-9 Amendment 132

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ------------------NOTES-----------------

1. With input from one power range neutron flux channel inoperable and THERMAL POWER s 75% RTP, the remaining three power range channels can be used for calculating QPTR.

2. SR 3.2.4.2 may be performed in lieu of this Surveillance if adequate power range neutron flux channel inputs are not OPERABLE.

Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control Program Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter with the QPTR alarm inoperable SR 3.2.4.2 -------------------------NOTE---------------------------

0 n ly required to be performed if input to QPTR from one or more power range neutron flux channels are inoperable with THERMAL POWER> 75% RTP.

Verify QPTR is within limit using either the movable Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months incore detectors or the PDMS.

In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.2-12 Amendment 82, 122, 132

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Y. One, two or three Turbine Y.1 Place channel(s) in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Stop Valve Closure channels inoperable. OR Y.2 Reduce THERMAL POWER to 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months

< P-9.

Z. Two RTS Trains inoperable Z.1 Enter LCO 3.0.3. Immediately SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 -------------------------NOTES-------------------

1. Adjust NIS channel if absolute difference is > 2%.

2. Required to be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is ~ 15% RTP.

Compare results of calorimetric heat In accordance with balance calculation to Nuclear the Surveillance Instrumentation System (NIS) channel Frequency Control output. Program (continued)

Watts Bar-Unit 1 3.3-10 Amendment 68, 132

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.3 ------------------------NOTES-------------------

1. Adjust NIS channel if absolute difference is~ 3%.

2. Required to be performed within 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months after THERMAL POWER is~ 15% RTP.

Compare results of the incore detector or PDMS In accordance with measurements to NIS AFD. the Surveillance Frequency Control Program SR 3.3.1.4 -------------------------NOTE----------------------

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 ------------------------NOTE----------------------

Requ ired to be performed within 6 days after THERMAL POWER is~ 50% RTP.

Calibrate excore channels to agree with incore detectors or In accordance with PDMS measurements. the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-11 Amendment 68, 82, 132

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.7 ---------------------NOTE-----------------------

For Functions 2 and 3 (Power Range Instrumentation),

this Surveillance shall include verification that interlock P-10 is in the required state for existing unit conditions.

Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.8 -----------------------NOTES-------------------- --------NOTE-----

1. Not required to be performed for Source Range Only required when not instrumentation prior to entering MODE 3 from MODE 2 performed within the until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3. frequency specified in the Surveillance

2. This Surveillance shall include verification that Frequency Control interlock P-6 is in the required state for Program existing unit conditions.

Perform COT. Prior to reactor startup Four hours after reducing power below P-10 for intermediate range instrumentation Four hours after reducing power below P-6 for source range instrumentation In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-12 Amendment 68, 132

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.9 --------------------NOTE--------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 ----------------------NOTE-------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.11 ----------------------NOTE--------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Perform COT. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-13 Amendment 132

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.13 ---------------------NOTE------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 --------------------------NOTE--------------------

Verification of setpoint is not required.

Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in Mode 3, if not performed within the previous 31 days SR 3.3.1.15 --------------------------NOTE-----------------------

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-14 Amendment 68, 132

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

0. One MSW Room Water Level --------*-----NOTE----------------

High channel inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

0.1 Place channel in trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 0.2 Be in MODE 3 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-31 Amendment 68, 132

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.4 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.5 ---------------------NO TE---------------------

Slave relays tested by SR 3.3.2.7 are excluded from this surveillance.

Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.6 --------------------NOTE-------------------

Verification of relay setpoints not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 Perform SLAVE RELAY TEST on slave relays K603A, In accordance with K603B, K604A,K604B, K607A,K607B,K609A, the Surveillance K609B, K612A, K625A, and K625B. Frequency Control Program SR 3.3.2.8 --------------------------NO TE-----------------------

Verification of setpoint not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-32 Amendment 17, 132

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.9 ---------------------NO TE--------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.10 --------------------NOTE--------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after~ 1092 psig in the steam generator.

Verify ESFAS RESPONSE TIMES are within In accordance with limit. the Surveillance Frequency Control Program SR 3.3.2.11 ---------------------NOTE-----------------------------

Verification of setpoint not required.

Perform TADOT. Once per reactor trip breaker cycle Watts Bar-Unit 1 3.3-33 Amendment 13, 132

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

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

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program SR 3.3.3.2 -------------------NOTES----------------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Not applicable to Functions 11 and 16.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.3.3 -----------------------NO TES---------------------------

1. Verification of relay setpoints not required.

2. Only applicable to Functions 11 and 16.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-43 Amendment 72, 132

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program SR 3.3.4.2 Verify each required control circuit and transfer switch In accordance with is capable of performing the intended function. the Surveillance Frequency Control Program SR 3.3.4.3 ----------------------NOTE-----------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required In accordance with instrumentation channel. the Surveillance Frequency Control Program SR 3.3.4.4 Perform TADOT of the reactor trip breaker In accordance with open/closed indication. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-47 Amendment 132

LOP DG Start Instrumentation 3.3.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIMI=

NO TE------------ C.1 Restore channel to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to Function 5 OPERABLE status.

C. One or more Functions with one channel per bus inoperable.

D. Required Action and D.1 Enter applicable Condition(s) Immediately associated Completion Time and Required Action(s) for the not met. associated DG made inoperable by LOP DG start instrumentation.

SURVEILLANCE REQUIREMENTS

NOTE---------------------------,-------------------------------

Refer to Table 3.3.5-1 to determine which SRs apply for each LOP Function.

SURVEILLANCE FREQUENCY SR 3.3.5.1 -------------------------NOTE--------------------

Verification of relay setpoints not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-50 Amendment 128, 132

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.5.2 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-50a Amendment 132

Containment Vent Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS

NO TE--------------------------------------------------

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Vent Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2 --------------------------NOTE--------------------------

This surveillance is only applicable to the actuation logic of the ESFAS instrumentation.

Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3 ---------------------------------NO TE-------------------------------

Th is surveillance is only applicable to the master relays of the ESFAS instrumentation.

Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4 Perform COT. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.3-54 Amendment 17, 68, 92 132

Containment Vent Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.6 -------------------------NOTE----------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.6. 7 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-54a Amendment 132

CREVS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Initiate action to restore one Immediately associated Completion Time CREVS train to OPERABLE for Condition A or B not met in status.

MODE 5 or 6.

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.7-1 to determine which SRs apply for each CREVS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.3 ---------------------NOTE---------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-59 Amendment 132

ABGTS Actuation Instrumentation 3.3.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Place both trains in Immediately emergency radiation protection mode.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A or B not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.8-1 to determine which SRs apply for each ABGTS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.8.1 --------------------------NOTE------------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.3-62 Amendment No. 92, 132

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is~ 2214 psig. In accordance with the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is :;; 593.2°F. In accordance with the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is~ 380,000 gpm (process In accordance with computer or control board indication). the Surveillance Frequency Control Program SR 3.4.1.4 ----------------------------NO TE----------------------------

Req uired to be performed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after

~90% RTP.

Verify by precision heat balance or elbow tap 6.p In accordance with method that RCS total flow rate is~ 380,000 gpm. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-2 Amendment 7, 47, 132

RCS Minimum Temperature for Criticality 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop~ 551°F. ---------NOTE--------

Only required if T avg - T ,et deviation alarm not reset and any RCS loop Tavg < 561°F In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-4 Amendment 132

RCS PIT Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -----------NOTE------------- C.1 Initiate action to restore Immediately Req uired Action C.2 shall be parameter(s) to within limits.

completed whenever this Condition is entered. AND C.2 Determine RCS is Prior to entering Requirements of LCO not met acceptable for continued MODE4 any time in other than operation.

MODE 1, 2, 3, or 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ----------------------------NOTE---------------------------

0 n ly required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and RCS heatup In accordance with and cooldown rates are within the limits specified in the the Surveillance PTLR. Frequency Control Program Watts Bar-Unit 1 3.4-6 Amendment 132

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not met. A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-7 Amendment 132

RCS Loops - MODE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop not in C.1 Restore required RCS loop to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months operation, and reactor trip operation.

breakers closed and Rod Control System capable of rod OR withdrawal.

C.2 De-energize all control rod 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months drive mechanisms (CRDMs).

D. All RCS loops inoperable. D.1 De-energize all CRDMs. Immediately OR AND No RCS loop in operation. D.2 Suspend all operations Immediately involving a reduction of RCS boron concentration.

AND D.3 Initiate action to restore one RCS loop to OPERABLE Immediately status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.4-9 Amendment 132

RCS Loops - MODE 3 3.4.5 SURVEILLANCE FREQUENCY SR 3.4.5.2 Verify steam generator secondary side water levels are greater In accordance with than or equal to 32% narrow range for required RCS loops. the Surveillance Frequency Control Program SR 3.4.5.3 Verify correct breaker alignment and indicated power are In accordance with available to the required pump that is not in operation. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-10 Amendment 61, 132

RCS Loops - MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify two RCS loop are in operation when the rod control In accordance with system is capable of rod withdrawal. the Surveillance Frequency Control Program SR 3.4.6.2 Verify one required RHR or RCS loop is in operation when the In accordance with rod control system is not capable of rod withdrawal. the Surveillance Frequency Control Program SR 3.4.6.3 Verify SG secondary side water levels are greater than or In accordance with equal to 32% narrow range for required RCS loops. the Surveillance Frequency Control Program SR 3.4.6.4 Verify correct breaker alignment and indicated power are In accordance with available to the required pump that is not in operation. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-13 Amendment 61, 104, 132

RCS Loops - Mode 5, Loops Filled 3.4.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving a reduction of RCS boron concentration.

OR No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4. 7.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side water level is greater than or equal In accordance with to 32% narrow range in required SGs. the Surveillance Frequency Control Program SR 3.4.7.3 Verify correct breaker alignment and indicated power are In accordance with available to the required RHR pump that is not in operation. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-15 Amendment 61, 132

RCS Loops - Mode 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving reduction in RCS boron concentration.

No RHR loop in operation.

B.2 Initiate action to restore one RHR loop to OPERABLE Immediately status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Watts Bar-Unit 1 3.4-17 Amendment 132

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is s 92%. In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of pressurizer In accordance with heaters is 2 150 kW. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-19 Amendment 132

Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. (continued) F.2 Restore one block valve to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

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

G.2 Be in MODE4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 ---------------------------NOTE--------------------------

Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.

Perform a complete cycle of each block valve. In accordance with the Surveillance Frequency Control Program.

SR 3.4.11.2 Perform a complete cycle of each PORV. In accordance with the Surveillance Frequency Control Program.

Watts Bar-Unit 1 3.4-24 Amendment 132

COMS

'3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify no safety injection pumps are capable of Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after injecting into the RCS. entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below 325°F.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.2 Verify a maximum of one charging pump is capable Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after of injecting into the RCS. entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below 325°F.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.3 Verify each accumulator is isolated. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.4-28 Amendment 132

COMS 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.4 -----------------NOTE------------------------

Only required to be performed when complying with LCO 3.4.12.b.

Verify RCS vent open. In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Verify PORV block valve is open for each required In accordance with PORV. the Surveillance Frequency Control Program SR 3.4.12.6 Verify both RHR suction isolation valves are locked In accordance with open with operator power removed for the required the Surveillance RHR suction relief valve. Frequency Control Program SR 3.4.12.7 -----------------------NO TE---------------------------

Requ ired to be met within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to::; 350°F.

Perform a COT on each required PORV, excluding In accordance with actuation. the Surveillance Frequency Control Program SR 3.4.12.8 Perform CHANNEL CALIBRATION for each required In accordance with PORVactuation channel. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-29 Amendment 132

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

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

2. Not applicable to primary-to-secondary LEAKAGE.

Verify RCS operational LEAKAGE is within limits by In accordance with the performance of RCS water inventory balance. Surveillance Frequency Control Program SR 3.4.13.2 ----------------------NOTE-------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary-to-secondary LEAKAGE is less than or In accordance with the equal to 150 gallons per day through any one SG. Surveillance Frequency Control Program Watts Bar-Unit 1 3.4-31 Amendment 65, 132

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -----------------------NOTES---------------------

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

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

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

Verify leakage from each RCS PIV is equivalent to In accordance with the

s; 0.5 gpm per nominal inch of valve size up to a lnservice Testing maximum of 5 gpm at an RCS pressure~ 2215 psig Program, and in and :s; 2255 psig. accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months (continued)

Watts Bar-Unit 1 3.4-34 Amendment 132

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance with containment atmosphere particulate radioactivity the Surveillance monitor. Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance with atmosphere particulate radioactivity level monitor. the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance with containment pocket sump level monitor. the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance with containment atmosphere particulate radioactivity the Surveillance monitor. Frequency Control Program Watts Bar-Unit 1 3.4-38 Amendment 71, 132

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time T avg < 500°F.

of Condition A not met.

OR DOSE EQUIVALENT 1-131

> 14 µCi/gm.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific In accordance with activity~ 100/ E µCi/gm. the Surveillance Frequency Control Program SR 3.4.16.2 ----------------------NOTE---------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 specific In accordance with activity :;; 0.265 µCi/gm. the Surveillance Frequency Control Program Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of ~ 15%

RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

Watts Bar-Unit 1 3.4-40 Amendment 41, 91, 132

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.16.3 --------------------NOTE----------------------

Required to be performed within 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for~ 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine E from a sample taken in MODE 1 after a In accordance with minimum of 2 effective full power days and 20 days of the Surveillance MODE 1 operation have elapsed since the reactor was Frequency Control last subcritical for~ 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . Program Watts Bar-Unit 1 3.4-41 Amendment 132

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. In accordance with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each accumulator is In accordance with 2: 7630 gallons and :s; 8000 gallons. the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is In accordance with 2: 610 psig and :s; 660 psig. the Surveillance Frequency Control Program SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance with 2: 3000 ppm and :s; 3300 ppm. the Surveillance Frequency Control Program

NOTE---------

Only required to be performed for affected accumulators.

Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of 2: 75 gallons, that is not the result of addition from the refueling water storage tank.

(continued)

Watts Bar-Unit 1 3.5-2 Amendment 7, 21, 40, 48, 67, 77, 107,132

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.5 Verify power is removed from each accumulator In accordance with isolation valve operator when pressurizer pressure* the Surveillance is ~ 1000 psig. Frequency Control Program Watts Bar-Unit 1 3.5-3 Amendment 132

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed In accordance with position with power to the valve operator the Surveillance removed. Frequency Control Program Number Position Function FCV-63-1 Open RHR Supply FCV-63-22 Open SIS Discharge SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance with automatic valve in the flow path, that is not locked, the Surveillance sealed, or otherwise secured in position, is in the Frequency Control correct position. Program SR 3.5.2.3 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program NOTE:

Surveillance performance not required for safety injection hot leg injection lines until start up from the Fall 2003 refueling outage.

SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the lnservice Testing developed head. Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow path In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program (continued)

Watts Bar-Unit 1 3.5-5 Amendment 43, 132

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Verify each ECCS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.5.2.7 Verify, for each ECCS throttle In accordance with valve listed below, each position the Surveillance stop is in the correct position. Frequency Control Program Valve Number CCP Discharge SI Cold Leg SI Hot Leg Throttle Throttle Throttle Valves Valves Valves63-582 63-550 63-542 63-583 63-552 63-544 63-584 63-554 63-546 63-585 63-556 63-548 SR 3.5.2.8 Verify, by visual inspection, each ECCS train In accordance with containment sump suction inlet is not restricted by the Surveillance debris and the suction inlet trash racks and screens Frequency Control show no evidence of structural distress or abnormal Program corrosion.

Watts Bar-Unit 1 3.5-6 Amendment 132

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 -----------------------NOTE---------------------------

Only required to be performed when ambient air temperature is< 60°F or> 105°F.

Verify RWST borated water temperature is In accordance with

~ 60°F and :S 105°F. the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is In accordance with

~ 370,000 gallons. the Surveillance Frequency Control Program SR 3.5.4.3 Verify boron concentration in the RWST is~ 3100 ppm In accordance with and :S 3300 ppm. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.5-10 Amendment 7, 40, 48, 67, 77, 107,132

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 ----------------------------NOTE----------------------------

Req uired to be performed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at 2 2215 psig and s 2255 psig.

Verify manual seal injection throttle valves are adjusted to In accordance with give a flow within limit with charging pump discharge the Surveillance header pressure 2 2430 psig and the pressurizer level Frequency Control control valve full open. Program Watts Bar-Unit 1 3.5-12 Amendment 132

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 ------------------------------NO TES------------------------

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rate Testing the Containment Program. Leakage Rate Testing Program.

SR 3.6.2.2 ----------------------------NOTE-------------------------

0 nly required to be performed upon entry or exit through the containment air lock.

Verify only one door in the air lock can be opened at a In accordance with time. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.6-7 Amendment 5, 132

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment purge valve is closed, except when In accordance with the containment purge valves are open for pressure control, the Surveillance ALARA or air quality considerations for personnel entry, or for Frequency Control Surveillances that require the valves to be open. Program SR 3.6.3.2 ----------------------NO TE-------------------------------

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

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

SR 3.6.3.3 ---------------------------NOTE-------------------------------

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

Verify each containment isolation manual valve and blind Prior to entering flange that is located inside containment, the containment M0DE4 from annulus, and the Main Steam Valve Vault Rooms, and not MODE 5 if not locked, sealed, or otherwise secured and required to be performed within the closed during accident conditions is closed, except for previous 92 days containment isolation valves that are open under administrative controls.

(continued)

Watts Bar-Unit 1 3.6-12 Amendment 79, 132

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.4 Verify the isolation time of each power operated and each In accordance with automatic containment isolation valve is within limits. the lnservice Testing Program or in accordance with the Surveillance Frequency Control Program SR 3.6.3.5 Perform leakage rate testing for containment purge valves In accordance with with resilient seals. the Containment Leakage Rate Testing Program SR 3.6.3.6 Verify each automatic containment isolation valve that is not In accordance with locked, sealed, or otherwise secured in position, actuates to the Surveillance the isolation position on an actual or simulated actuation Frequency Control signal. Program SR 3.6.3.7 Verify each 24 inch containment lower compartment purge In accordance with supply and exhaust isolation valve is blocked to restrict the the Surveillance valve from opening> 50°. Frequency Control Program (continued)

Watts Bar-Unit 1 3.6-13 Amendment 123, 132

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be ~ -0.1 and :;;; +0.3 psid relative to the annulus.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. --------NOTE---------- A.1 Restore containment pressure 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to within limits.

When opening or closing Penetration 1-EQH-271-0010 or 1-EQH-271-0011 in the Shield Building Dome during Cycle 7 operation, time is allowed for Containment Annulus pressure equalization to occur.

Containment pressure not within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.6-15 Amendment 59, 132

Containment Air Temperature 3.6.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment upper compartment average air In accordance with temperature is within limits. the Surveillance Frequency Control Program SR 3.6.5.2 Verify containment lower compartment average air In accordance with temperature is within limits. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.6-17 Amendment 132

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power operated, In accordance with and automatic valve in the flow path that is not locked, the Surveillance sealed, or otherwise secured in position is in the correct Frequency Control position. Program SR 3.6.6.2 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required the lnservice Testing developed head. Program SR 3.6.6.3 Verify each automatic containment spray valve in the flow In accordance with path that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual or Frequency Control simulated actuation signal. Program SR 3.6.6.4 Verify each containment spray pump starts automatically In accordance with on an actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.6.6.5 Verify each spray nozzle is unobstructed. At first refueling AND In accordance with the Surveillance Frequency Control Program SR 3.6.6.6 Perform SR 3.5.2.2 and SR 3.5.2.4 for the RHR spray In accordance with system. Applicable SRs Watts Bar-Unit 1 3.6-19 Amendment 132

HMS 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Energize each HMS train power supply breaker and verify In accordance with the

~33* ignitors are energized in each train. Surveillance Frequency Control Program*

See Note below SR 3.6.8.2 Verify at least one hydrogen ignitor is OPERABLE in each In accordance with the containment region. Surveillance Frequency Control Program SR 3.6.8.3 Energize each hydrogen ignitor and verify temperature is In accordance with the

~1700°F. Surveillance Frequency Control Program For the time period between June 9, 1998, and the next WBN Unit 1 entry into MODE 3, SR 3.6.8.1 shall verify~ 32 ignitors are OPERABLE on HMS Train A at a frequency of 46 days.

Watts Bar-Unit 1 3.6-23 Amendment 10, 132

EGTS 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Emergency Gas Treatment System (EGTS)

LCO 3.6.9 Two EGTS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One EGTS train inoperable. A.1 Restore EGTS train to 7 days OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Operate each EGTS train for ~ 15 continuous minutes In accordance with with heaters operating. the Surveillance Frequency Control Program SR 3.6.9.2 Perform required EGTS filter testing in accordance with In accordance the Ventilation Filter Testing Program (VFTP). with the VFTP (continued)

Watts Bar-Unit 1 3.6-24 Amendment 115, 132

EGTS 3.6.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.9.3 Verify each EGTS train actuates on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program SR 3.6.9.4 Verify each EGTS train produces a flow rate ;;:: 3600 and In accordance with

~ 4400 cfm within 20 seconds from the initiation of a the Surveillance Containment Isolation Phase A signal. Frequency Control Program Watts Bar-Unit 1 3.6-25 Amendment 132

ARS 3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Air Return System (ARS)

LCO 3.6.10 Two ARS trains shall be OPERABLE.

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

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

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Verify each ARS fan starts on an actual or simulated In accordance with actuation signal, after a delay of::::: 8.0 minutes and the Surveillance

,; 10.0 minutes, and operates for::::: 15 minutes. Frequency Control Program SR 3.6.10.2 Verify, with the ARS fan dampers closed, each ARS fan In accordance with motor current is ::::: 54 amps and :,; 94 amps. the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.6-26 Amendment 132

ARS 3.6.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.10.3 Verify, with the ARS fan not operating, each ARS fan In accordance with damper opens when ::; 92.4 in-lb is applied. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.6-27 Amendment 132

Ice Bed 3.6.11 3.6 CONTAINMENT SYSTEMS 3.6.11 Ice Bed LCO 3.6.11 The ice bed shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Ice bed inoperable. A.1 Restore ice bed to OPERABLE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months status.

B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND 8.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.11.1 Verify maximum ice bed temperature is::; 27°F. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.6-28 Amendment 132

Ice Bed 3.6.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.11.2 Verify total weight of stored ice is greater than or In accordance with equal to 2,404,500 lb by: the Surveillance Frequency Control

a. Weighing a representative sample of 2: 144 Program ice baskets and verifying each basket contains greater than or equal to 1237 lb of ice; and

b. Calculating total weight of stored ice, at a 95 percent confidence level, using all ice basket weights determined in SR 3.6.11.2.a.

SR 3.6.11.3 Verify azimuthal distribution of ice at a 95 percent In accordance with confidence level by subdividing weights, as the Surveillance determined by SR 3.6.11.2.a, into the following Frequency Control groups: Program

a. Group 1-bays 1 through 8;

b. Group 2-bays 9 through 16; and

c. Group 3-bays 17 through 24.

The average ice weight of the sample baskets in each group from radial rows 1, 2, 4, 6, 8, and 9 shall be greater than or equal to 1237 lb.

SR 3.6.11.4 Verify, by visual inspection, accumulation of ice on In accordance with structural members comprising flow channels through the Surveillance the ice bed is less than or equal to 15 percent Frequency Control blockage of the total flow area for each safety analysis Program section.

(continued)

Watts Bar-Unit 1 3.6-29 Amendment 2, 25, 33, 62, 132

Ice Bed 3.6.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.11.5 ------------------------NOTE-----------------------

The requirements of this SR are satisfied if the boron concentration and pH values obtained from averaging the individual sample results are within the limits specified below.

Verify, by chemical analysis of the stored ice in at In accordance with least one randomly selected ice basket from each ice the Surveillance condenser bay, that ice bed: Frequency Control Program

a. Boron concentration is ~ 1800 ppm and s 2000 ppm; and

b. pH is~ 9.0 ands 9.5.

SR 3.6.11.6 Visually inspect, for detrimental structural wear, In accordance with cracks, corrosion, or other damage, two ice baskets the Surveillance from each azimuthal group of bays. See SR 3.6.11.3. Frequency Control Program SR 3.6.11.7 ---------------------------NO TE--------------------------

The chemical analysis may be performed on either the liquid solution or on the resulting ice.

Verify, by chemical analysis, that ice added to the ice Each ice addition condenser meets the boron concentration and pH requirements of SR 3.6.11.5.

Watts Bar-Unit 1 3.6-30 Amendment 22, 132

Ice Condenser Doors 3.6.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Restore ice condenser door 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months associated Completion Time to OPERABLE status and of Condition B not met. closed positions.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or C not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.12.1 Verify all inlet doors indicate closed by the Inlet Door In accordance with Position Monitoring System. the Surveillance Frequency Control Program SR 3.6.12.2 Verify, by visual inspection, each intermediate deck door In accordance with is closed and not impaired by ice, frost, or debris. the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.6-32 Amendment 3, 132

Ice Condenser Doors 3.6.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.12.3 Verify, by visual inspection, each inlet door is not impaired -------NOTE--------

by ice, frost, or debris. The 3 month performance due September 9, 1996 (per SR 3.0.2) may be extended until October 21 , 1996.

3 months during first year after receipt of license In accordance with the Surveillance Frequency Control Program SR 3.6.12.4 Verify torque required to cause each inlet door to begin to ---------NOTE---------

open is :$ 675 in-lb. The 3 month performance due September 9, 1996 (per SR 3.0.2) may be extended until October 21, 1996.

3 months during first year after receipt of license In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.6-33 Amendment 3, 132

Ice Condenser Doors 3.6.12 SURVEILLANCE REQUIREMENTS (Continued)

SURVEILLANCE FREQUENCY SR 3.6.12.5 Perform a torque test on a sampling of~ 50% of the inlet --------NOTE---

doors. The 3 month performance due September 9, 1996 (per SR 3.0.2) may be extended until October 21 , 1996.

3 months during first year after receipt of license In accordance with the Surveillance Frequency Control Program SR 3.6.12.6 Verify for each intermediate deck door: 3 months during first

a. No visual evidence of structural deterioration; year after receipt of license

b. Free movement of the vent assemblies; and

c. Free movement of the door.

In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.6-34 Amendment 3, 132

Ice Condenser Doors 3.6.12 SURVEILLANCE REQUIREMENTS (Continued)

SURVEILLANCE FREQUENCY SR 3.6.12.7 Verify, by visual inspection, each top deck door: In accordance with the Surveillance

a. Is in place; Frequency Control Program

b. Free movement of top deck vent assembly; and

c. Has no condensation, frost, or ice formed on the door that would restrict its opening.

Watts Bar-Unit 1 3.6-34a Amendment 3, 132

Divider Barrier Integrity 3.6.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.13.1 Verify, by visual inspection, all personnel access doors and Prior to entering equipment hatches between upper and lower containment MODE4 from compartments are closed. MODES SR 3.6.13.2 Verify, by visual inspection, that the seals and sealing Prior to final closure surfaces of each personnel access door and equipment after each opening hatch have:

AND

a. No detrimental misalignments;

NO TE--------

b. No cracks or defects in the sealing surfaces; and On ly required for seals made of C. No apparent deterioration of the seal material. resilient materials In accordance with the Surveillance Frequency Control Program SR 3.6.13.3 Verify, by visual inspection, each personnel access door or After each opening equipment hatch that has been opened for personnel transit is closed.

SR 3.6.13.4 Verify, by peel test on three specimens for each Prior to initial fuel replacement seal repair location, that the length of peel for loading for joints at least two of the test specimens is less than or equal to 1 made prior to fuel inch. loading (continued)

Watts Bar-Unit 1 3.6-36 Amendment 132

Divider Barrier Integrity 3.6.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.13.4 (continued) 18 months for the first two refueling outages after fabrication of any joint 18 months thereafter for a fabricated splice joint, if any of the three test specimens peel length is > 1/2 inch 36 months thereafter for a fabricated splice joint, if all three associated test specimens peel length is :s: 1/2 inch SR 3.6.13.5 Visually inspect ;,: 95% of the divider barrier seal length, In accordance with and verify: the Surveillance Frequency Control

a. Seal and seal mounting bolts are properly Program installed; and

b. Seal material shows no evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical appearance.

Watts Bar-Unit 1 3.6-37 Amendment 132

Containment Recirculation Drains 3.6.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.6.14.1 Verify, by visual inspection, that: In accordance with the Surveillance

a. Each refueling canal drain plug is removed; Frequency Control Program

b. Each refueling canal drain is not obstructed by debris; and C. No debris is present in the upper compartment or Prior to entering refueling canal that could obstruct the refueling MODE4 from canal drain. MODE 5 after each partial or complete fill of the canal SR 3.6.14.2 Verify for each ice condenser floor drain that the: In accordance with the Surveillance

a. Gate opening is not impaired by ice, frost, or debris; Frequency Control Program

b. Gate seat shows no evidence of damage;

c. Gate opening force is :s: 100 lb; and

d. Drain line from the ice condenser floor to the lower compartment is unrestricted.

Watts Bar-Unit 1 3.6-39 Amendment 132

Shield Building 3.6.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.15.1 Verify annulus negative pressure is In accordance with equal to or more negative than -5 inches water the Surveillance gauge with respect to the atmosphere. Frequency Control Program SR 3.6.15.2 Verify the door in each access opening is closed, In accordance with except when the access opening is being used for the Surveillance normal transient entry and exit. Frequency Control Program SR 3.6.15.3 Verify shield building structural integrity by During shutdown performing a visual inspection of the exposed for SR 3.6.1.1 interior and exterior surfaces of the shield building. Type A tests SR 3.6.15.4 Verify each Emergency Gas Treatment System In accordance with train with final flow ?:: 3600 and ::; 4400 cfm the Surveillance produces an annulus pressure equal to or more Frequency Control negative than -0.61 inch water gauge at elevation Program 783 with respect to the atmosphere and with an inleakage of::; 250 cfm.

Watts Bar-Unit 1 3.6-41 Amendment 132

MSIVs 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C not met. AND D.2 Be in MODE4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 ------------------------NO TE---------------------------

Req uired to be performed in MODE 3.

Verify closure time of each MSIV is:;;. 6.0 seconds on In accordance with an actual or simulated actuation signal. the lnservice Testing Program or in accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-6 Amendment 132

MFIVs and MFRVs and Associated Bypass Valves 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more MFIV or MFRV C.1 Restore bypass valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months bypass valves inoperable. OPERABLE status.

D. One MFIV and MFRV in the D.1 Isolate affected flow path. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months same flow path inoperable.

E. One MFIV bypass valve and E.1 Restore one MFIV bypass 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months MFRV bypass valve in the valve or MFRV bypass valve same flow path inoperable. to OPERABLE status.

F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND F.2 Be in MODE4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the closure time of each MFIV, MFRV, and In accordance with associated bypass valve is :o; 6.5 seconds on an actual or the lnservice Testing simulated actuation signal. Program or in accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-8 Amendment 132

ADVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ADV. In accordance with the Surveillance Frequency Control Program SR 3.7.4.2 Verify one complete cycle of each ADV block valve. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-10 Amendment 132

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and In accordance with automatic valve in each water flow path, and in both the Surveillance steam supply flow paths to the steam turbine driven Frequency Control pump, that is not locked, sealed, or otherwise secured Program in position, is in the correct position.

SR 3.7.5.2 ------------------------NO TE--------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after~ 1092 psig in the steam generator.

Verify the developed head of each AFW pump at the In accordance with flow test point is greater than or equal to the required the lnservice Testing developed head. Program SR 3.7.5.3 -----------------------NO TE-------------------------

Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW automatic valve that is not locked, In accordance with sealed, or otherwise secured in position, actuates to the Surveillance the correct position on an actual or simulated Frequency Control actuation signal. Program (continued)

Watts Bar-Unit 1 3.7-13 Amendment 13, 132

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.5.4 --------------------------NOTES-----------------------

1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after;;;: 1092 psig in the steam generator.

2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.5.5 Verify proper alignment of the required AFW flow paths Prior to entering by verifying flow from the condensate storage tank to MODE 2 after initial each steam generator. fuel loading and whenever unit has been in MODE 5 or 6 for> 30 days Watts Bar-Unit 1 3.7-14 Amendment 13, 132

CST 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is 2 200,000 gal. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-16 Amendment 132

ccs 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify that the alternate feeder breaker to the C-S pump is In accordance with open. the Surveillance Frequency Control Program SR 3.7.7.2 -----------------------------NO TE---------------------------

lsolation of CCS flow to individual components does not render the CCS inoperable.

Verify each CCS manual, power operated, and automatic In accordance with valve in the flow path servicing safety related equipment, the Surveillance that is not locked, sealed, or otherwise secured in Frequency Control position, is in the correct position. Program SR 3.7.7.3 Verify each CCS automatic valve in the flow path that is In accordance with not locked, sealed, or otherwise secured in position, the Surveillance actuates to the correct position on an actual or simulated Frequency Control actuation signal. Program SR 3.7.7.4 ----------------------NO TE--------------------------------------

Verification of CCS pump 2B-B automatic start on Unit 1 SI is not required when CCS Pump 2B-B is supporting CCS Train B OPERABILITY.

Verify each CCS pump starts automatically on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.7.5 ----------------------NOTE-------------------------------------

On ly required to be met when CCS Pump 2B-B is supporting CCS Train B OPERABILITY.

Verify each CCS pump 2B-B is aligned to CCS Train B In accordance with and is in operation. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-18 Amendment 113, 132

ERCW 3.7.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND

met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Two Train A ERCW pumps C.1 Align the operable pumps (C-A 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (A-A and B-A) inoperable and D-A) to concurrently and two Train A ERCW autostart from the 2A-A 6.9 KV pumps operable (C-A and Shutdown Board.

D-A).

AND C.2 Restore at least one of the 10 days pumps (A-A or B-A) to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ------------------------NO TE-------------------------

lsolation of ERCW flow to individual components does not render the ERCW inoperable.

Verify each ERCW manual, power operated, and In accordance with automatic valve in the flow path servicing safety the Surveillance related equipment, that is not locked, sealed, or Frequency Control otherwise secured in position, is in the correct Program position.

(continued)

This CONDITION will apply until the A-A or B-A pump is repaired and declared operable or until July 31, 2008, whichever occurs first.

Watts Bar-Unit 1 3.7-20 Amendment 69, 132

ERCW 3.7.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.8.2 Verify each ERCW automatic valve in the flow path In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.8.3 Verify each ERCW pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-20a Amendment 132

UHS 3.7.9

3. 7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)

LCO 3.7.9 The UHS shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS inoperable. A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify average water temperature of UHS is ::; 85°F. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-21 Amendment 132

CREVS 3.7.10

3. 7 PLANT SYSTEMS

3. 7.10 Control Room Emergency Ventilation System (CREVS)

LCO 3.7.10 Two CREVS trains shall be OPERABLE.

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

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREVS train A.1 Restore CREVS train to 7 days inoperable for reasons other OPERABLE status.

than Condition B.

B. One or more CREVS trains B.1 Initiate action to implement Immediately inoperable due to mitigating actions.

inoperable CRE boundary in Mode 1, 2, 3, or 4. AND B.2 Verify mitigating actions ensure 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months CRE occupant exposures to radiological and chemical hazards will not exceed limits and CRE occupants are protected from smoke hazards.

AND B.3 Restore CRE boundary to 90 days OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met in MODE 1, 2, 3, or 4. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

Watts Bar-Unit 1 3.7-22 Amendment 35, 70, 112, 132

CREVS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Place OPERABLE CREVS Immediately associated Completion train in emergency mode.

Time of Condition A not met in MODE 5 or 6, or during OR movement of irradiated fuel assemblies. D.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CREVS trains E.1 Restore one CREVS train to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable in MODE 1, 2, 3, OPERABLE status.

or 4 due to actions taken as a result of a tornado warning.

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

F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. Two CREVS trains G.1 Suspend movement of Immediately inoperable in MODE 5 or 6, irradiated fuel assemblies.

or during movement of irradiated fuel assemblies.

QB One or more CREVS trains inoperable due to inoperable CRE boundary in Mode 5 or 6, or during movement of irradiated fuel assemblies.

(continued)

Watts Bar-Unit 1 3.7-23 Amendment 35, 70, 94, 132

CREVS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Two CREVS trains H.1 Enter LCO 3.0.3 Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B or E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7 .10.1 Operate each CREVS train for ;:: 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3. 7.10.2 Perform required CREVS filter testing in accordance with the In accordance with Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.10.3 Verify each CREVS train actuates on an actual or simulated In accordance with actuation signal. the Surveillance Frequency Control Program SR 3.7.10.4 Perform required CRE unfiltered air inleakage testing in In accordance with accordance with the Control Room Habitability Program. the Control Room Envelope Habitability Program Watts Bar-Unit 1 3.7-24 Amendment 70, 94, 132

CREATCS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two CREATCS trains 0.1 Suspend movement of Immediately inoperable in MODE 5 or 6, or irradiated fuel assemblies.

during movement of irradiated fuel assemblies.

E. Two CREATCS trains E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each CREATCS train has the capability to remove In accordance with the assumed heat load. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-26 Amendment 35, 132

ABGTS 3.7.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ABGTS train for:?: 15 continuous In accordance with minutes with the heaters operating. the Surveillance Frequency Control Program SR 3.7.12.2 Perform required ABGTS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.12.3 Verify each ABGTS train actuates on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.12.4 Verify one ABGTS train can maintain a pressure In accordance with between -0.25 and -0.5 inches water gauge with the Surveillance respect to atmospheric pressure during the post Frequency Control accident mode of operation at a flow rate :?: 9300 and Program

9900 cfm.

Watts Bar-Unit 1 3.7-28 Amendment No. 92, 115, 132

Fuel Storage Pool Water Level 3.7.13

3. 7 PLANT SYSTEMS 3.7.13 Fuel Storage Pool Water Level LCO 3.7.13 The fuel storage pool water level shall be ~ 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool water level A.1 -------------NO TE----------

not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the fuel storage pool water level is In accordance with

~ 23 ft above the top of the irradiated the Surveillance fuel assemblies seated in the storage Frequency Control racks. Program Watts Bar-Unit 1 3.7-29 Amendment 132

Secondary Specific Activity 3.7.14

3. 7 PLANT SYSTEMS

3. 7 .14 Secondary Specific Activity LCO 3.7.14 The specific activity of the secondary coolant shall be :s: 0.10 µCi/gm DOSE EQUIVALENT 1-131.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months limit.

AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the specific activity of the secondary coolant is In accordance with

s; 0.10 µCi/gm DOSE EQUIVALENT 1-131. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-30 Amendment 132

CCS - Shutdown 3.7.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7.16.1 Verify correct breaker alignment and indicated power In accordance with available to the required pump(s) that is not in the Surveillance operation. Frequency Control Program SR 3.7.16.2 Verify two CCS pumps are aligned to CCS Train B. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 1 3.7-35 Amendment 104, 132

ERCW - Shutdown 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify correct breaker alignment and indicated In accordance with the power available to the required pump(s) that is Surveillance Frequency not in operation. Control Program Watts Bar - Unit 1 3.7-38 Amendment 104, 132

Fuel Storage Pool Boron Concentration 3.7.18 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.18.1 Verify the fuel storage pool boron concentration is In accordance within limit. with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.7-40 Amendment 125, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 --------------------------NO TES-----------------------

1. Performance of SR 3.8.1. 7 satisfies this SR.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each DG starts from standby conditions and As specified in achieves steady state voltage ~ 6800 V and ::;; 7260 Table 3.8.1-1 V, and frequency of 60 Hz nominal.

(continued)

Watts Bar-Unit 1 3.8-6 Amendment 102, 103, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 ----------------------NOTES-------------------

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded and As specified in operates for~ 60 minutes at a load~ 3960 kW and Table 3.8.1-1

4400kW.

SR 3.8.1.4 Verify each skid mounted day tank contains In accordance with

~ 218.5 gal of fuel oil. the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each In accordance with skid mounted day tank. the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from 7 day storage tank the Surveillance to the skid mounted day tank. Frequency Control Program (continued)

Watts Bar-Unit 1 3.8-7 Amendment 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 Verify each DG starts from standby condition and In accordance with achieves in ::;; 10 seconds, voltage ~ 6800 V, and the Surveillance frequency~ 58.8 Hz. Verify after DG fast start from Frequency Control standby conditions that the DG achieves steady state Program voltage ~ 6800 V and ::;; 7260 V, and frequency ~ 59.8 Hz and ::;; 60.1 Hz.

SR 3.8.1.8 --------------------------NOTES----------------------------

1. For the 1A-A and 1B-B Shutdown Boards, this Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

2. Transfer capability is only required to be met for 6.9 kV shutdown boards that required normal and alternate power supplies.

Verify automatic and manual transfer of each 6.9 kV In accordance with shutdown board power supply from the normal offsite the Surveillance circuit to each alternate offsite circuit. Frequency Control Program (continued)

Watts Bar-Unit 1 3.8-8 Amendment 89, 102, 103, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9 --------------------------NOTES----------------------

1. For DGs 1A-A and 18-B, this Surveillance shall not be performed in MODE 1 or 2.

However, credit may be taken for unplanned events that satisfy this SR.

2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor~ 0.8 and :s; 0.9.

Verify each DG rejects a load greater than or equal to In accordance with its associated single largest post-accident load, and: the Surveillance Frequency Control

a. Following load rejection, the frequency is Program

s; 66.75 Hz;

b. Within 3 seconds following load rejection, the voltage is ~ 6555 V and :s; 7260 V; and

c. Within 4 seconds following load rejection, the frequency is ~ 59.8 Hz and :s; 60.1 Hz.

SR 3.8.1.10 -----------------------NO TE---------------------------

For DGs 1A-A and 1B-8, this Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor~ 0.8 and In accordance with

s; 0.9 does not trip and voltage is maintained :s; 8880 V the Surveillance during and following a load rejection of~ 3960 kW and Frequency Control

s; 4400 kW and~ 2970 kVAR and :s; 3300 kVAR. Program (continued)

Watts Bar-Unit 1 3.8-9 Amendment 89, 102, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 -------------------------NOTE-------------------------

For DGs 1A-A and 18-8, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power In accordance with signal: the Surveillance Frequency Control

a. De-energization of emergency buses; Program

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in :s; 10 seconds,

2. energizes auto-connected shutdown loads through automatic load sequencer,

3. maintains steady state voltage e:: 6800 V and :s; 7260 V,

4. maintains steady state frequency

: -: 59.8 Hz and :s; 60.1 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for e:: 5 minutes.

(continued)

Watts Bar-Unit 1 3.8-10 Amendment 89, 102, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ---------------------NOTE----------------------

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Engineered Safety In accordance with Feature (ESF) actuation signal each Unit 1 DG the Surveillance auto-starts from standby condition and: Frequency Control Program

a. In s 10 seconds after auto-start and during tests, achieves voltage ~ 6800 V and frequency ~ 58.8 Hz;

b. After DG fast start from standby conditions the DG achieves steady state voltage ~ 6800 V and s 7260 V, and frequency~ 59.8 Hz and s 60.1 Hz.

c. Operates for~ 5 minutes;

d. Permanently connected loads remain energized from the offsite power system; and

e. Emergency loads are energized from the offsite power system.

(continued)

Watts Bar-Unit 1 3.8-11 Amendment 102, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 --------------------------NOTE------------------------

For DGs 1A-A and 18-8, this Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are bypassed on In accordance with automatic or emergency start signal except: the Surveillance Frequency Control

a. Engine overspeed; and Program

b. Generator differential current.

SR 3.8.1.14 ------------------------NOTES-------------------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. For performance of this test in MODE 1, 2, 3 or 4, three DGs must be maintained operable and in a standby condition.

3. Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor~ 0.8 and In accordance with s 0.9 operates for~ 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: the Surveillance Frequency Control

a. For~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 4620 kW and Program s 4840 kW and~ 3465 kVAR ands 3630 kVAR; and

b. For the remaining hours of the test loaded

~ 3960 kW and s 4400 kW and ~ 2970 kVAR and s 3300 kVAR.

(continued)

Watts Bar-Unit 1 3.8-12 Amendment 12, 89, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15 ----------------------------NOTE-----------------------

Th is Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded;;;

3960 kW and

,;; 4400 kW.

Momentary transients outside of load range do not invalidate this test.

Verify each DG starts and achieves, in :,;; 10 seconds, In accordance with voltage;;;: 6800 V, and frequency;;;: 58.8 Hz. Verify the Surveillance after DG fast start from standby conditions that the DG Frequency Control achieves steady state voltage ;;;: 6800 V and Program

,;; 7260 V, and frequency ~ 59.8 Hz and :,;; 60.1 Hz.

SR 3.8.1.16 ------------------------NO TE--------------------------

For DGs 1A-A and 1B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG: In accordance with the Surveillance

a. Synchronizes with offsite power source while Frequency Control loaded with emergency loads upon a Program simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

(continued)

Watts Bar-Unit 1 3.8-13 Amendment 89, 102, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17 ------------------------NOTE---------------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify, with each Unit 1 DG operating in test mode and In accordance with connected to its bus, an actual or simulated ESF the Surveillance actuation signal overrides the test mode by: Frequency Control Program

a. Returning DG to ready-to-load operation; and

b. Automatically energizing the emergency load from offsite power.

SR 3.8.1.18 --------------------------NOTE---------------------------

For DGs 1A-A and 1B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify the time delay setting for each sequenced load In accordance with block is within limits for each accident condition and the Surveillance non-accident condition load sequence. Frequency Control Program (continued)

Watts Bar-Unit 1 3.8-14 Amendment 89, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 -------------------------NO TE---------------------------

For DGs 1A-A and 1B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power In accordance with signal in conjunction with an actual or simulated ESF the Surveillance actuation signal: Frequency Control Program

a. De-energization of emergency buses;

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in :;; 10 seconds,

2. energizes auto-connected emergency loads through load sequencer,

3. achieves steady state voltage:

~ 6800 V and :;; 7260 V,

4. achieves steady state frequency

~ 59.8 Hz and :;; 60.1 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

SR 3.8.1.20 Verify during idle operation that any automatic or In accordance with emergency start signal disables the idle start circuitry the Surveillance and commands the engine to full speed. Frequency Control Program (continued)

Watts Bar-Unit 1 3.8-15 Amendment 89, 102, 110, 132

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.21 Verify when started simultaneously from standby In accordance with condition, each DG achieves, in ::;; 10 seconds, the Surveillance voltage;:::: 6800 V and frequency;:::: 58.8 Hz. Verify Frequency Control after DG fast start from standby conditions that the Program DG achieves steady state voltage ;:::: 6800 V and

7260 V, and frequency ;

: :: 59.8 Hz and ::;; 60.1 Hz.

SR 3.8.1.22 ---------------------NO TES-------------------------

1. For the 1B and 1C Unit Boards, this Surveillance shall not normally be performed in MODE 1 or 2.

However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

2. Transfer capability is only required to be met for 6.9 kV unit boards that require normal and alternate power supplies.

Verify automatic transfer of each 6.9 kV Unit Board In accordance with 1B, 1C, 28, and 2C power supple from the normal the Surveillance power supply to the alternate power supply. Frequency Control Program Watts Bar-Unit 1 3.8-16 Amendment 102, 103, 132

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with new D.1 Restore stored fuel oil 30 days fuel oil properties not within properties to within limits.

limits.

E. One or more DGs with E.1 Restore starting air receiver 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months starting air receiver pressure to ~ 190 psig.

pressure < 190 psig and

~ 170 psig.

F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each 7 day fuel oil storage tank contains In accordance with

~ 56,754 gal of fuel. the Surveillance Frequency Control Program (continued)

Watts Bar-Unit 1 3.8-22 Amendment 132

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.3.2 Verify lubricating oil inventory is ~ 287 gal per engine. In accordance with the Surveillance Frequency Control Program SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each DG air start receiver pressure is In accordance with

~ 190 psig. the Surveillance Frequency Control Program SR 3.8.3.5 Check for and remove accumulated water from each In accordance with of the four interconnected tanks which constitute the 7 the Surveillance day fuel oil storage tank. Frequency Control Program SR 3.8.3.6 Perform a visual inspection for leaks in the exposed In accordance with fuel oil system piping while the DG is running. the Surveillance Frequency Control Program SR 3.8.3.7 For each of the four interconnected tanks which In accordance with constitute the 7 day fuel oil storage tank: the Surveillance Frequency Control

a. Drain the fuel oil; Program

b. Remove the sediment; and C. Clean the tank.

Watts Bar-Unit 1 3.8-23 Amendment 132

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify vital battery terminal voltage is greater than or In accordance with equal to the minimum established float voltage. the Surveillance Frequency Control Program SR 3.8.4.2 Verify DG battery terminal voltage is greater than or In accordance with equal to the minimum established float voltage. the Surveillance Frequency Control Program SR 3.8.4.3 Verify for the vital batteries that the alternate feeder In accordance with breakers to each required battery charger are open. the Surveillance Frequency Control Program SR 3.8.4.4 Verify correct breaker alignment and indicated power In accordance with availability for each DG 125 V DC distribution panel the Surveillance and associated battery charger. Frequency Control Program SR 3.8.4.5 Verify each vital battery charger supplies ~ 200 amps In accordance with at greater than or equal to the minimum established the Surveillance float voltage for~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Frequency Control Program Verify each vital battery charger can recharge the battery to the fully charged state within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.

(continued)

Watts Bar-Unit 1 3.8-26 Amendment 130, 132

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.6 --------------------NOTE------------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG DC battery charger can recharge the In accordance with battery to the fully charged state within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months while the Surveillance supplying the largest combined demands of the Frequency Control various continuous steady state loads, after a battery Program discharge to the bounding design basis event discharge state.

SR 3.8.4.7 -----------------------NOTES-----------------------

1. The modified performance discharge test in SR 3.8.6. 7 may be performed in lieu of the service test in SR 3.8.4.7.

2. This Surveillance is not performed in MODE 1, 2, 3, or 4 for required vital batteries.

Credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required the Surveillance emergency loads and any connected nonsafety loads Frequency Control for the design duty cycle when subjected to a battery Program service test.

Watts Bar-Unit 1 3.8-27 Amendment 54, 130, 132

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 -----------------------NOTE------------------------

Not required to be met when vital battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify each vital battery float current is :s; 2 amps. In accordance with the Surveillance Frequency Control Program SR 3.8.6.2 ----------------------NO TE---------------------------

Not required to be met when DG battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.2.

Verify each DG battery float current is :s; 1 amp. In accordance with the Surveillance Frequency Control Program SR 3.8.6.3 Verify each required vital battery and each DG In accordance with battery pilot cell float voltage is;:;:: 2.07 V. the Surveillance Frequency Control Program SR 3.8.6.4 Verify each required vital battery and each DG In accordance with battery connected cell electrolyte level is greater than the Surveillance or equal to minimum established design limits. Frequency Control Program SR 3.8.6.5 Verify each required vital battery and each DG In accordance with battery pilot cell temperature is greater than or equal the Surveillance to minimum established design limits. Frequency Control Program (continued)

Watts Bar-Unit 1 3.8-35 Amendment 130, 132

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.6 Verify each required vital battery and each DG In accordance with battery connected cell float voltage is.:: 2.07 V. the Surveillance Frequency Control Program SR 3.8.6.7 -------------------------NOTES----------------------

Th is Surveillance is not performed in MODE 1, 2, 3, or 4 for required vital batteries. Credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is ~ 80% of the manufacturer's In accordance with rating when subjected to a performance discharge the Surveillance test or a modified performance discharge test. Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity

~ 100% of manufacturer's rating Watts Bar-Unit 1 3.8-36 Amendment 130, 132

Inverters-Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and In accordance with alignment to required AC vital bus. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.8-38 Amendment 129, 132

Inverters-Shutdown 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and In accordance with alignments to required AC vital bus. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.8-40 Amendment 129, 132

Distribution Systems-Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND G.2 Bein MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. Two trains with one or H.1 Enter LCO 3.0.3. Immediately more inoperable distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance with required AC, vital DC, and AC vital bus electrical the Surveillance power distribution subsystems. Frequency Control Program Watts Bar-Unit 1 3.8-42a Amendment 129, 132

Distribution Systems Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to restore Immediately required AC, vital DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to In accordance with required AC, vital DC, and AC vital bus electrical power the Surveillance distribution subsystems. Frequency Control Program Watts Bar-Unit 1 3.8-44 Amendment 132

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.

APPLICABILITY: MODE6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. ALTERA TIONS.

AND A.2 Suspend positive reactivity Immediately additions.

AND A.3 Initiate action to restore boron Immediately concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified In accordance with in COLR. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.9-1 Amendment 55, 132

Unborated Water Source Isolation Valves 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water In accordance with sources is secured in the closed position. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.9-3 Amendment 132

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 -----------------------NOTE--------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 1 3.9-5 Amendment 132

RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) 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 SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of:?: 2500 gpm. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.9-9 Amendment 132

RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR loop in operation. B.1 Suspend operations involving a Immediately reduction in reactor coolant boron concentration.

AND B.2 Initiate action to restore one Immediately RHR loop to operation.

B.3 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 SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of;;:: 2000 gpm. the Surveillance Frequency Control Program SR 3.9.6.2 Verify correct breaker alignment and indicated power In accordance with available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Watts Bar-Unit 1 3.9-11 Amendment 132

Refueling Cavity Water Level 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water level is :?: 23 ft above the In accordance with top of reactor vessel flange. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.9-13 Amendment 132

Spent Fuel Pool Boron Concentration 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Spent Fuel Pool Boron Concentration LCO 3.9.9 Boron concentration of the spent fuel pool shall be 2 2300 ppm.

APPLICABILITY: Whenever any fuel assembly is stored in the flooded spent fuel pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Initiate action to restore fuel Immediately not within limit. storage pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify boron concentration in the spent fuel pool is In accordance with

2: 2300 ppm. the Surveillance Frequency Control Program Watts Bar-Unit 1 3.9-16 Amendment 125, 132

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals 5.7.2.23 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

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

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

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

Watts Bar-Unit 1 5.0-25c Amendment 132

TENNESSEE VALLEY AUTHORITY DOCKET NO. 50-391 WATTS BAR NUCLEAR PLANT, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 36 License No. NPF-96

1. The U.S. Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Tennessee Valley Authority (TVA, the licensee) dated October 12, 2018; as supplemented by letters dated May 7, June 6, and August 29, 2019; and January 17, 2020; complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

Enclosure 2

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-96 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A as revised through Amendment No. 36 and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. TVA shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 60 days, except for the changes to Technical Specification Surveillance Requirements 3.7.18.1 and 3.9.9.1. The changes to Technical Specification Surveillance Requirements 3.7.18.1 and 3.9.9.1 shall be implemented prior to startup from the outage where any number of tritium producing burnable absorber rods is inserted in the Watts Bar Nuclear Plant, Unit 2 reactor core, not to exceed December 31, 2022.

FOR THE NUCLEAR REGULATORY COMMISSION

/RA/ G. Edward Miller for Undine Shoop, Chief Plant Licensing Branch II-2 Division of operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Operating License and Technical Specifications Date of Issuance: February 28, 2020

ATTACHMENT TO AMENDMENT NO. 36 WATTS BAR NUCLEAR PLANT, UNIT 2 FACILITY OPERATING LICENSE NO. NPF-96 DOCKET NO. 50-391 Replace page 3 of Facility Operating License No. NPF-96 with the attached revised page 3.

Replace the following pages of the Appendix A Technical Specifications with the attached pages. The revised pages are identified by amendment number and contain vertical lines indicating the area of change.

Remove Insert Remove Insert 3.1-1 3.1-1 3.4-3 3.4-3 3.1-2 3.1-2 3.4-5 3.4-5 3.1-4 3.1-4 3.4-6 3.4-6 3.1-9 3.1-9 3.4-8 3.4-8 3.1-11 3.1-11 -- 3.4-8a 3.1-14a 3.1-14a 3.4-11 3.4-11 3.1-19 3.1-19 3.4-13 3.4-13

-- 3.1-19a 3.4-15 3.4-15 3.1-21 3.1-21 3.4-17 3.4-17 3.2-3 3.2-3 3.4-22 3.4-22

-- 3.2-4 3.4-26 3.4-26 3.2-5 3.2-5 3.4-27 3.4-27 3.2-7 3.2-7 3.4-29 3.4-29 3.2-8 3.2-8 3.4-32 3.4-32 3.2-11 3.2-11 3.4-34 3.4-34 3.3-10 3.3-10 3.4-36 3.4-36 3.3-11 3.3-11 3.4-37 3.4-37 3.3-12 3.3-12 3.5-2 3.5-2 3.3-13 3.3-13 -- 3.5-2a 3.3-14 3.3-14 3.5-4 3.5-4 3.3-31 3.3-31 3.5-5 3.5-5 3.3-32 3.3-32 3.5-9 3.5-9

-- 3.3-33 3.5-11 3.5-11 3.3-44 3.3-44 3.6-6 3.6-6 3.3-49 3.3-49 3.6-12 3.6-12 3.3-52a 3.3-52a 3.6-13 3.6-13 3.3-56 3.3-56 3.6-14 3.6-14 3.3-57 3.3-57 3.6-16 3.6-16 3.3-61 3.3-61 3.6-18 3.6-18 3.3-64 3.3-64 3.6-21 3.6-21 3.4-2 3.4-2 3.6-22 3.6-22

Remove Insert Remove Insert 3.6-23 3.6-23 3.8-5 3.8-5 3.6-24 3.6-24 3.8-6 3.8-6

-- 3.6-24a -- 3.8-6a 3.6-25 3.6-25 3.8-7 3.8-7 3.6-26 3.6-26 3.8-8 3.8-8 3.6-27 3.6-27 3.8-9 3.8-9 3.6-29 3.6-29 3.8-10 3.8-10 3.6-30 3.6-30 3.8-11 3.8-11 3.6-32 3.6-32 3.8-12 3.8-12 3.6-34 3.6-34 3.8-13 3.8-13 3.6-36 3.6-36 3.8-19 3.8-19 3.7-5 3.7-5 3.8-20 3.8-20 3.7-7 3.7-7 3.8-23 3.8-23 3.7-9 3.7-9 3.8-24 3.8-24 3.7-12 3.7-12 3.8-31 3.8-31 3.7-15 3.7-15 3.8-32 3.8-32 3.7-17 3.7-17 3.8-34 3.8-34 3.7-19 3.7-19 3.8-36 3.8-36 3.7-20 3.7-20 3.8-38a 3.8-38a 3.7-23 3.7-23 3.8-40 3.8-40

-- 3.7-23a 3.9-1 3.9-1 3.7-25 3.7-25 3.9-2 3.9-2 3.7-27 3.7-27 3.9-4 3.9-4 3.7-28 3.7-28 3.9-7 3.9-7 3.7-29 3.7-29 3.9-9 3.9-9 3.7-33 3.7-33 3.9-10 3.9-10 3.7-36 3.7-36 3.9-12 3.9-12 3.7-38 3.7-38 5.0-27b 5.0-27b

C. The license shall be deemed to contain and is subject to the conditions specified in the Commissions regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act, and to the rules, regulations, and orders of the Commission now or hereafter in effect, and is subject to the additional conditions specified or incorporated below.

(1) Maximum Power Level TVA is authorized to operate the facility at reactor core power levels not in excess of 3411 megawatts thermal.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A as revised through Amendment No. 36 and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. TVA shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) TVA shall implement permanent modifications to prevent overtopping of the embankments of the Fort Loudon Dam due to the Probable Maximum Flood by June 30, 2018.

(4) PAD4TCD may be used to establish core operating limits until the WBN Unit 2 steam generators are replaced with steam generators equivalent to the existing steam generators at WBN Unit 1.

(5) By December 31, 2019, the licensee shall report to the NRC that the actions to resolve the issues identified in Bulletin 2012-01, Design Vulnerability in Electrical Power System, have been implemented.

(6) The licensee shall maintain in effect the provisions of the physical security plan, security personnel training and qualification plan, and safeguards contingency plan, and all amendments made pursuant to the authority of 10 CFR 50.90 and 50.54(p).

(7) TVA shall fully implement and maintain in effect all provisions of the Commission approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The TVA approved CSP was discussed in NUREG-0847, Supplement 28, as amended by changes approved in License Amendment No. 7.

(8) TVA shall implement and maintain in effect all provisions of the approved fire protection program as described in the Fire Protection Report for the facility, as described in NUREG-0847, Supplement 29, subject to the following provision:

Unit 2 Facility Operating License No. NPF-96 Amendment No. 36

SOM - Tavg > 200°F 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)-Tavg > 200°F LCO 3.1.1 SOM shall be 2:: 1.6% ~k/k.

APPLICABILITY: MODE 2 with keff < 1.0, MODES 3 and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SOM not within limit. A.1 Initiate boration to restore 15 minutes SOM to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SOM is 2:: 1.6% ~k/k. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.1-1 Amendment 36

SOM - Tavg s 200°F 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 SHUTDOWN MARGIN (SOM) - Tavg s 200°F LCO 3.1.2 The SDM shall be~ 1.0% ~k/k.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore 15 minutes SDM to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify SDM is~ 1.0% ~k/k. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.1-2 Amendment 36

Core Reactivity 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 ------------------------------NOTE-------------------------------

The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.

Verify measured core reactivity is within +/- 1% Llk/k of Once prior to predicted values. entering MODE 1 after initial fuel loading and each refueling AND

NOTE---------

0 nly required after 60 EFPD In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.1-4 Amendment 36

Rod Group Alignment Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 -----------------------------NOTES--------------------------

1. Not required to be performed for rods associated with inoperable rod position indicator or demand position indicator.

2. Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify position of individual rods within alignment In accordance with limit. the Surveillance Frequency Control Program Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod position deviation monitor is inoperable SR 3.1.5.2 Verify rod freedom of movement (tripability) by In accordance with moving each rod not fully inserted in the core the Surveillance

~ 10 steps in either direction. Frequency Control Program SR 3.1.5.3 Verify rod drop time of each rod, from the fully Prior to criticality withdrawn position, is s 2.7 seconds from the after each removal beginning of decay of stationary gripper coil voltage of the reactor head to dashpot entry, with:

a. Tav9 ~ 551°F; and

b. All reactor coolant pumps operating.

Watts Bar - Unit 2 3.1-9 Amendment 20, 36

Shutdown Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more shutdown 8.1.1 Verify SOM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months banks not within limits for limits specified in the reasons other than COLR.

Condition A OR 8.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SOM to with limit.

AND 8.2 Restore shutdown banks 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to within limits.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 ------------------------------NO TE---------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify each shutdown bank is within the insertion In accordance with

-limits specified in the COLR. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.1-11 Amendment 20, 36

Control Bank Insertion Limits 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.2 ------------------------NOTE-------------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify each control bank insertion is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod insertion limit monitor is inoperable SR 3.1.7.3 -------------------------NOTE-------------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after associated rod motion.

Verify sequence and overlap limits specified in the In accordance with COLR are met for control banks not fully withdrawn the Surveillance from the core_. Frequency Control Program Watts Bar - Unit 2 3.1-14a Amendment 20, 36

PHYSICS TESTS Exceptions - MODE 1 3.1.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. THERMAL POWER not 8.1 Reduce THERMAL 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limit. POWER to within limit.

OR 8.2 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months TESTS exceptions C. Power Range Neutron C. 1 Restore Power Range 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Flux - High trip setpoints Neutron Flux - High trip

> 10% RTP above the setpoints to s 10% above PHYSICS TEST power the PHYSICS TEST level. power level, or to s 90% RTP, whichever is OR lower.

Power Range Neutron OR Flux - High trip setpoints

> 90% RTP. C.2 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months TESTS exceptions.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Verify THERMAL POWER is s 85% RTP. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.1-19 Amendment 36

PHYSICS TESTS Exceptions - MODE 1 3.1.9 SURVEILLANCE REQUREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.9.2 Verify Power Range Neutron Flux - High trip Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months prior setpoints are ::; 10% above the PHYSICS TESTS to initiation of power level, and::; 90% RTP. PHYSICS TESTS SR 3.1.9.3 Perform SR 3.2.1.1 and SR 3.2.2.1. In accordance with

the Surveillance Frequency Control Program SR 3.1.9.4 Verify SOM is ;?: 1.6% ~k/k. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.1-19a Amendment 36

PHYSICS TESTS Exceptions - MODE 2 3.1.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop average C.1 Restore RCS lowest loop 15 minutes temperature not within limit. average temperature to within limit.

D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.10.1 Perform a CHANNEL OPERATIONAL TEST on Prior to initiation of power range and intermediate range channels per PHYSICS TESTS SR 3.3.1.7, SR 3.3.1.8, and Table 3.3.1-1.

SR 3.1.10.2 Verify the RCS lowest loop average temperature is In accordance with

~ 541°F. the Surveillance Frequency Control Program SR 3.1.10.3 Verify SOM is ~ 1.6% Lik/k. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.1-21 Amendment 36

Fa(Z) 3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS

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

During power escalation at the beginning of each cycle, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained.

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify Fae (Z) is within limit. Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by

10% RTP, the THERMAL POWER at which Fae (Z) was last verified (continued)

Watts Bar - Unit 2 3.2-3 Amendment 36

Fa(Z) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.1.1 In accordance with (continued) the Surveillance Frequency Control Program SR 3.2.1.2 -------------------------------NO TE------------------------------

1f Faw (Z), increased by the appropriate factor specified in the COLR, is not within limits:

Repeat SR 3.2.1.2 once per 7 EFPD using the Power Distribution Monitoring System (PDMS) until two successive incore power distribution measurements indicate Maximum over z

[FC(z)]

icz)

Fe (Z)*W(Z)]

Maximum over z [ Q K(Z) have not increased.

Verify Faw (Z) is within limit. Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP (continued)

Watts Bar - Unit 2 3.2-4 Amendment 36

Fa(Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 Once within (continued) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by

2: 10% RTP, the THERMAL POWER at which Faw (Z) was last verified In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.2-5 Amendment 36

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 -------------NOTE------------

THERMAL POWER does not have to be reduced to comply with this Required Action.

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER reaching ~ 95% RTP B. Required Action and 8.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify FfH is within limits specified in the COLR. Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.2-7 Amendment 36

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)

LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the -COLR.

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

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.

APPLICABILITY: MODE 1 with THERMAL POWER=:! 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to< 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE REQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore In accordance with channel. the Surveillance Frequency Control Program Once within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter with the AFD monitor alarm inoperable Watts Bar - Unit 2 3.2-8 Amendment 36

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 -------------------------------NOTES----------------------------

a. With input from one power range neutron flux channel inoperable and THERMAL POWER s 75% RTP, the remaining three power range channels can be used for calculating QPTR.

b. SR 3.2.4.2 may be performed in lieu of this Surveillance if adequate power range neutron flux channel inputs are not OPERABLE.

Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control Program Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter with the QPTR alarm inoperable SR 3.2.4.2 -------------------------------NOTE------------------------------

Only required to be performed if input to QPTR from one or more power range neutron flux channels are inoperable with THERMAL POWER> 75% RTP.

Verify QPTR is within limit using the PDMS. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.2-11 Amendment 21, 36

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Y. One, two or three Turbine Y. 1 Place channel(s) in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Stop Valve Closure channels inoperable. OR Y.2 Reduce THERMAL 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months POWER to < P-9.

Z. Two RTS Trains inoperable. Z.1 Enter LCO 3.0.3. Immediately SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 -------------------------------NO TES----------------------------

1. Adjust NIS channel if absolute difference is> 2%.

2. Required to be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is ~ 15% RTP.

Compare results of calorimetric heat balance In accordance with calculation to Nuclear Instrumentation System (NIS) the Surveillance channel output. Frequency Control Program (continued)

Watts Bar - Unit 2 3.3-10 Amendment 36

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.3 -------------------------------NOTES----------------------------

1. Adjust NIS channel if absolute difference is z 3%.

2. Required to be performed within 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months after THERMAL POWER is z 25% RTP.

Compare results of the PDMS measurements to In accordance with NISAFD. the Surveillance Frequency Control Program SR 3.3.1.4 -------------------------------NO TE------------------------------

T his Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 ------------------------------NO TE------------------------------

Req uired to be performed within 6 days after THERMAL POWER is z 50% RTP.

Calibrate excore channels to agree with the PDMS In accordance with measurements. the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.3-11 Amendment 36

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.7 -------------------------------NOTE------------------------------

For Functions 2 and 3 (Power Range Instrumentation), this Surveillance shall include verification that interlock P-10 is in the required state for existing unit conditions.

Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.8 -------------------------------NOTES---------------------------- ----------NOTE---------

1. Not required to be performed for Source Range On ly required when instrumentation prior to entering MODE 3 from not performed within MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3. the frequency specified in the

2. This Surveillance shall include verification that Surveillance interlock P-6 is in the required state for existing Frequency Control unit conditions. Program Perform COT. Prior to reactor startup Four hours after reducing power below P-1 O for intermediate range instrumentation Four hours after reducing power below P-6 for source range instrumentation (continued)

Watts Bar - Unit 2 3.3-12 Amendment 36

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.8 In accordance with (continued) the Surveillance Frequency Control Program SR 3.3.1.9 -----------------------------NOTE------------------------------

Verificatio n of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 -------------------------------NOTE------------------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.11 -------------------------------NOTE------------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Perform COT. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.3-13 Amendment 36

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.13 ------------------------------NOTE------------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 -------------------------------NOTE-----------------------------

Verification of setpoint is not required.

Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in MODE 3, if not performed within the previous 31 days.

SR 3.3.1.15 -------------------------------NOTE------------------------------

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-14 Amendment 36

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.4 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.5 -------------------------------NOTE------------------------------

Slave relays tested by SR 3.3.2. 7 are excluded from this surveillance.

Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.3-31 Amendment 36

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.6 -------------------------------NOTE------------------------------

Verificati on of relay setpoints not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 Perform SLAVE RELAY TEST on slave relays In accordance with K603A, K603B, K604A, K604B, K607A, K607B, the Surveillance K609A, K609B, K612A, K625A, and K625B. Frequency Control Program SR 3.3.2.8 ------------------------------NOTE------------------------------

Verification of setpoint not required for manual initiation.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.9 ------------------------------NOTE------------------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.3-32 Amendment 36

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.10 ------------------------------NO TE-----------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after .!: 1092 psig in the steam generator.

Verify ESFAS RESPONSE TIMES are within limit. In accordance with the Surveillance Frequency Control Program SR 3.3.2.11 -------------------------------NOTE------------------------------

Verification of setpoint not required.

Perform TADOT. Once per reactor trip breaker cycle Watts Bar - Unit 2 3.3-33 Amendment 36

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

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

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program SR 3.3.3.2 -------------------------------NOTES---------------------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Not applicable to Functions 11 and 16.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.3.3 -------------------------------NOTES----------------------------

1. Verification of relay setpoints not required.

2. Only applicable to Functions 11 and 16.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-44 Amendment 36

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program SR 3.3.4.2 Verify each required control circuit and transfer In accordance with switch is capable of performing the intended function. the Surveillance Frequency Control Program SR 3.3.4.3 -------------------------------NOTE-----------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required In accordance with instrumentation channel. the Surveillance Frequency Control Program SR 3.3.4.4 Perform TADOT of the reactor trip breaker In accordance with open/closed indication. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-49 Amendment 36

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5-1 to determine which SRs apply for each LOP Function.

SURVEILLANCE FREQUENCY SR 3.3.5.1 -----------------------------NO TE------------------------------

Verificatio n of relay setpoints not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-52a Amendment 31, 36

Containment Vent Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Vent Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2 -------------------------------NO TE-----------------------------

Th is surveillance is only applicable to the actuation logic of the ESFAS instrumentation.

Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3 -------------------------------NOTE------------------------------

This surveillance is only applicable to the master relays of the ES FAS instrumentation.

Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4 Perform COT. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar- Unit 2 3.3-56 Amendment 36

Containment Vent Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.6 -------------------------------NOTE------------------------------

Ve rifi cation of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.6. 7 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-57 Amendment 36

CREVS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.7-1 to determine which SRs apply for each CREVS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.3 -------------------------------NOTE------------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-61 Amendment 36

ABGTS Actuation Instrumentation 3.3.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) 8.2 Place both trains in Immediately emergency radiation protection mode.

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

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 -------------------------------NOTE------------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.3-64 Amendment 36

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is :2: 2214 psig. In accordance with the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is :s; 593.2°F. In accordance with the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is :2: 380,000 gpm (process In accordance with computer or control board indication). the Surveillance Frequency Control Program SR 3.4.1.4 -------------------------------NOTE------------------------------

Required to be performed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after

2: 90% RTP.

Verify by precision heat balance method that RCS In accordance with total flow rate is :2: 380,000 gpm. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-2 Amendment 36

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (Tavg} shall be :2: 551°F.

APPLICABILITY: MODE 1, MODE 2 with kett :2: 1.0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Tavg in one or more RCS A.1 Be in MODE 3. 30 minutes loops not within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop :2: 551°F. ----------NO TE---------

0 nly required if T avg - T ret deviation alarm not reset and any RCS loop Tavg< 561°F.

In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-3 Amendment 36

RCS PIT Limits 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ------------------------------NOTE------------------------------

0 n ly required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and RCS In accordance with heatup and cooldown rates are within the limits the Surveillance specified in the PTLR. Frequency Control Program Watts Bar - Unit 2 3.4-5 Amendment 36

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-6 Amendment 36

RCS Loops - MODE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop not C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in operation, and reactor trip loop to operation.

breakers closed and Rod Control System capable of OR rod withdrawal.

C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDMs).

D. All RCS loops inoperable. D. 1 De-energize all CRDMs. Immediately OR AND No RCS loop in operation. D.2 Suspend all operations Immediately involving a reduction of RCS boron concentration.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify steam generator secondary side water levels In accordance with are ;:,,: 6% narrow range for required RCS loops. the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.4-8 Amendment 36

RCS Loops - MODE 3 3.4.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.5.3 Verify correct breaker alignment and indicated power In accordance with are available to the required pump that is not in the Surveillance operation. Frequency Control Program Watts Bar - Unit 2 3.4-8a Amendment 36

RCS Loops - MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify two RCS loops are in operation when the rod In accordance with control system is capable of rod withdrawal. the Surveillance Frequency Control Program SR 3.4.6.2 Verify one required RHR or RCS loop is in operation In accordance with when the rod control system is not capable of rod the Surveillance withdrawal. Frequency Control Program SR 3.4.6.3 Verify SG secondary side water levels are greater In accordance with than or equal to 6% narrow range for required RCS the Surveillance loops. Frequency Control Program SR 3.4.6.4 Verify correct breaker alignment and indicated power In accordance with are available to the required pump that is not in the Surveillance operation. Frequency Control Program Watts Bar - Unit 2 3.4-11 Amendment 8, 36

RCS Loops - MODE 5, Loops Filled 3.4.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops 8.1 Suspend all operations Immediately inoperable. involving a reduction of RCS boron concentration.

AND No RHR loop in operation.

8.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4. 7 .1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4. 7 .2 Verify SG secondary side water level is greater than In accordance with or equal to 6% narrow range in required SGs. the Surveillance Frequency Control Program SR 3.4.7.3 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Watts Bar - Unit 2 3.4-13 Amendment 36

RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops 8.1 Suspend all operations Immediately inoperable. involving reduction in RCS boron concentration.

AND No RHR loop in operation.

8.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Watts Bar - Unit 2 3.4-15 Amendment 36

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is :s: 92%. In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of pressurizer In accordance with heaters is~ 150 kW. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-17 Amendment 36

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.

G.2 Be in MODE4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 -------------------------------NOTE-----------------------------

Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.

Perform a complete cycle of each block valve. In accordance with the Surveillance Frequency Control Program SR 3.4.11.2 Perform a complete cycle of each PORV. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-22 Amendment 36

COMS 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify no safety injection pumps are capable of Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after injecting into the RCS. entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below the COMS arming temperature specified in the PTLR.

AND In accordance with the Surveillance Frequency Control Program SR 3.4.12.2 Verify a maximum of one charging pump is capable Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after of injecting into the RCS. *entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below the COMS arming temperature specified in the PTLR.

AND In accordance with the Surveillance Frequency Control Program SR 3.4.12.3 Verify each accumulator is isolated. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.4-26 Amendment 36

COMS 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.4 ------------------------------NOTE------------------------------

Only required to be performed when complying with LCO 3.4.12.b.

Verify RCS vent open. In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Verify PORV block valve is open for each required In accordance with PORV. the Surveillance Frequency Control Program SR 3.4.12.6 Verify both RHR suction isolation valves are locked In accordance with open with operator power removed for the required the Surveillance RHR suction relief valve. Frequency Control Program SR 3.4.12.7 ------------------------------NOTE------------------------------

Required to be met within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to less than or equal to the COMS arming temperature specified in the PTLR.

Perform a COT on each required PORV, excluding In accordance with actuation. the Surveillance Frequency Control Program SR 3.4.12.8 Perform CHANNEL CALIBRATION for each required In accordance with PORV actuation channel. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-27 Amendment 36

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

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

2. Not applicable to primary-to-secondary LEAKAGE.

Verify RCS operational LEAKAGE is within limits by In accordance with performance of RCS water inventory balance. the Surveillance Frequency Control Program SR 3.4.13.2 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary-to-secondary LEAKAGE is less than In accordance with or equal to 150 gallons per day through any one SG. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.4-29 Amendment 36

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -------------------------------NOTE------------------------------

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

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

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

Verify leakage from each RCS PIV is equivalent to In accordance with

s: 0.5 gpm per nominal inch of valve size up to a the Inservice Testing maximum of 5 gpm at an RCS pressure~ 2215 psig Program, and in and :s: 2255 psig. accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve Watts Bar - Unit 2 3.4-32 Amendment 36

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. All required monitors D.1 Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance with containment atmosphere particulate radioactivity the Surveillance monitor. Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance with atmosphere particulate radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance with containment pocket sump level monitor. the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance with containment atmosphere particulate radioactivity the Surveillance monitor. Frequency Control Program Watts Bar - Unit 2 3.4-34 Amendment 36

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C. 1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Tavg < 500°F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131

> 14 µCi/gm.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity In accordance with s 1001 E µCi/gm. the Surveillance Frequency Control Program SR 3.4.16.2 -------------------------------NOTE------------------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance with specific activity s 0.265 µCi/gm. the Surveillance Frequency Control Program Between 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of

~ 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

Watts Bar - Unit 2 3.4-36 Amendment 36

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.16.3 -----------------------------NO TE------------------------------

Req uired to be performed within 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 2 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine E from a sample taken in MODE 1 after a In accordance with minimum of 2 effective full power days and 20 days the Surveillance of MODE 1 operation have elapsed since the reactor Frequency Control was last subcritical for 2 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . Program Watts Bar - Unit 2 3.4-37 Amendment 36

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. In accordance with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each accumulator is In accordance with 2 7630 gallons and s 8000 gallons. the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is In accordance with 2 610 psig and s 660 psig. the Surveillance Frequency Control Program SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance with 2 3000 ppm ands 3300 ppm. the Surveillance Frequency Control Program AND

NOTE---------

Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of 2 75 gallons, that is not the result of addition from the refueling water storage tank (continued)

Watts Bar - Unit 2 3.5-2 Amendment 36

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.5 Verify power is removed from each accumulator In accordance with isolation valve operator when pressurizer pressure is the Surveillance

1000 psig. Frequency Control Program Watts Bar - Unit 2 3.5-2a Amendment 36

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position In accordance with with power to the valve operator removed. the Surveillance Frequency Control Number Position Function Program 2-FCV-63-1 Open RHR Supply 2-FCV-63-22 Open SIS Discharge SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance with automatic valve in the flow path, that is not locked, the Surveillance sealed, or otherwise secured in position, is in the Frequency Control correct position. Program SR 3.5.2.3 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the lnservice Testing developed head. Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow path In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.5.2.6 Verify each ECCS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.5-4 Amendment 36

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, In accordance with each position stop is in the correct position. the Surveillance Frequency Control Program Valve Number CCP SI SI Discharge Cold Leg Hot Leg Throttle Throttle Throttle Valves Valves Valves 2-63-582 2-63-550 2-63-542 2-63-583 2-63-552 2-63-544 2-63-584 2-63-554 2-63-546 2-63-585 2-63-556 2-63-548 SR 3.5.2.8 Verify, by visual inspection, each ECCS train In accordance with containment sump suction inlet is not restricted by the Surveillance debris and the suction inlet trash racks and screens Frequency Control show no evidence of structural distress or abnormal Program corrosion.

Watts Bar - Unit 2 3.5-5 Amendment 36

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 -----------------------------NOTE------------------------------

0 n ly required to be performed when ambient air temperature is< 60 °For> 105 °F.

Verify RWST borated water temperature is In accordance with

~ 60 °F and::; 105 °F. the Surveillance Frequency Control Program SR 3.5 ..4.2 Verify RWST borated water volume is In accordance with

~ 370,000 gallons. the Surveillance Frequency Control Program SR 3.5.4.3 Verify boron concentration in the RWST is In accordance with

~ 3100 ppm and::; 3300 pp_m. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.5-9 Amendment 36

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 ----------------------------NO TE------------------------------

Req u ired to be performed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at

2215 psig and

::; 2255 psig.

Verify manual seal injection throttle valves are In accordance with adjusted to give a flow within limit with charging the Surveillance pump discharge header pressure ;;::: 2430 psig and Frequency Control the pressurizer level control valve full open. Program Watts Bar - Unit 2 3.5-11 Amendment 36

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 -------------------------------NO TES---------------------------

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rate the Containment Testing Program. Leakage Rate Testing Program SR 3.6.2.2 ------------------------------NOTE------------------------------

Only required to be performed upon entry or exit through the containment air lock.

Verify only one door in the air lock can be opened at In accordance with a time. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.6-6 Amendment 36

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment purge valve is closed, In accordance with except when the containment purge valves are open the Surveillance for pressure control, ALARA or air quality Frequency Control considerations for personnel entry, or for Program Surveillances that require the valves to be open.

SR 3.6.3.2 ------------------------------NOTE------------------------------

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

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

SR 3.6.3.3 -------------------------------NOTE------------------------------

Va Ives and blind flanges in high radiation areas may be verified by use of administrative controls.

Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment, the MODE 4from containment annulus, and the Main Steam Valve MODE 5 if not Vault Rooms, and not locked, sealed, or otherwise performed within the secured and required to be closed during accident previous 92 days conditions is closed, except for containment isolation valves that are open under administrative controls.

SR 3.6.3.4 Verify the isolation time of each power operated and In accordance with each automatic containment isolation valve is within the lnservice Testing limits. Program or in accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.6-12 Amendment 36

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.5 Perform leakage rate testing for containment purge In accordance with valves with resilient seals. the Containment Leakage Rate Testing Program SR 3.6.3.6 Verify each automatic containment isolation valve In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the isolation position on an Frequency Control actual or simulated actuation signal. Program SR 3.6.3.7 Verify each 24 inch containment lower compartment In accordance with purge supply and exhaust isolation valve is blocked the Surveillance to restrict the valve from opening > 50°. Frequency Control Program SR 3.6.3.8 Verify the combined leakage rate for all shield In accordance with building bypass leakage paths is ::; 0.25 La when the Containment pressurized to ~ 15.0 psig. Leakage Rate Testing Program Watts Bar- Unit 2 3.6-13 Amendment 24, 36

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be 2 -0.1 and :s; +0.3 psid relative to the annulus.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure not A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limits. pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.6-14 Amendment 36

Containment Air Temperature 3.6.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment upper compartment average air In accordance with temperature is within limits. the Surveillance Frequency Control Program SR 3.6.5.2 Verify containment lower compartment average air In accordance with temperature is within limits. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.6-16 Amendment 36

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance with operated, and automatic valve in the flow path that is the Surveillance not locked, sealed, or otherwise secured in position Frequency Control is in the correct position. Program SR 3.6.6.2 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservice Testing the required developed head. Program SR 3.6.6.3 Verify each automatic containment spray valve in the In accordance with flow path that is not locked, sealed, or otherwise the Surveillance secured in position, actuates to the correct position Frequency Control on an actual or simulated actuation signal. Program SR 3.6.6.4 Verify each containment spray pump starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program SR 3.6.6.5 Verify each spray nozzle is unobstructed. At first refueling AND In accordance with the Surveillance Frequency Control Program SR 3.6.6.6 Perform SR 3.5.2.2 and SR 3.5.2.4 for the RHR In accordance with spray system. Applicable SRs Watts Bar - Unit 2 3.6-18 Amendment 36

HMS 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Energize each HMS train power supply breaker and In accordance with verify :2: 33 igniters are energized in each train. the Surveillance Frequency Control Program SR 3.6.8.2 Verify at least one hydrogen igniter is OPERABLE in In accordance with each containment region. the Surveillance Frequency Control Program SR 3.6.8.3 Energize each hydrogen igniter and verify In accordance with temperature is;;;: 1700 °F. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.6-21 Amendment 36

EGTS 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Emergency Gas Treatment System (EGTS)

LCO 3.6.9 Two EGTS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One EGTS train inoperable. A.1 Restore EGTS train to 7 days OPERABLE status.

B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND 8.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Operate each EGTS train for c:: 15 continuous In accordance with minutes with heaters operating. the Surveillance Frequency Control Program SR 3.6.9.2 Perform required EGTS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP (continued)

Watts Bar - Unit 2 3.6-22 Amendment 15, 36

EGTS 3.6.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.9.3 Verify each EGTS train actuates on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program SR 3.6.9.4 Verify each EGTS train produces a flow rate In accordance with

~ 3600 cfm and ::;; 4400 cfm within 20 seconds from the Surveillance the initiation of a Containment Isolation Phase A Frequency Control signal. Program Watts Bar - Unit 2 3.6-23 Amendment 36

ARS 3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Air Return System (ARS)

LCO 3.6.10 Two ARS trains shall be OPERABLE.

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

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

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Verify each ARS fan starts on an actual or simulated In accordance with actuation signal, after a delay of 2 8.0 minutes and the Surveillance s 10.0 minutes, and operates for 2 15 minutes. Frequency Control Program SR 3.6.10.2 Verify, with the ARS fan dampers closed, each ARS In accordance with fan motor current is 2 54 amps and s 94 amps. the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.6-24 Amendment 36

ARS 3.6.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.10.3 Verify, with the ARS fan not operating, each ARS fan In accordance with damper opens when :;;; 92.4 in-lb is applied. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.6-24a Amendment 36

Ice Bed 3.6.11 3.6 CONTAINMENT SYSTEMS

.3.6.11 Ice Bed LCO 3.6.11 The ice bed shall be OPERABLE APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Ice bed inoperable. A.1 Restore ice bed to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OPERABLE status.

B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND 8.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.11.1 Verify maximum ice bed temperature is::;; 27°F. In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.6-25 Amendment 36

Ice Bed 3.6.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.11.2 Verify total weight of stored ice is greater than or In accordance with equal to 2,404,500 lb by: the Surveillance Frequency Control

a. Weighing a representative sample of:::: 144 ice Program baskets and verifying each basket contains greater than or equal to 1237 lb of ice; and

b. Calculating total weight of stored ice, at a 95 percent confidence level, using all ice basket weights determined in SR 3.6.11.2.a.

SR 3.6.11.3 Verify azimuthal distribution of ice at a 95 percent In accordance with confidence level by subdividing weights, as the Surveillance determined by SR 3.6.11.2.a, into the following Frequency Control groups: Program

a. Group 1-bays 1 through 8;

b. Group 2-bays 9 through 16; and

c. Group 3-bays 17 through 24.

The average ice weight of the sample baskets in each group from radial rows 1, 2, 4, 6, 8, and 9 shall be greater than or equal to 1237 lb.

SR 3.6.11.4 Verify, by visual inspection, accumulation of ice on In accordance with structural members comprising flow channels the Surveillance through the ice bed is less than or equal to Frequency Control 15 percent blockage of the total flow area for each Program safety analysis section.

(continued)

Watts Bar - Unit 2 3.6-26 Amendment 14, 36

Ice Bed 3.6.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.11.5 ------------------------NOTE----------------------------------

The requirements of this SR are satisfied if the boron concentration and pH values obtained from averaging the individual sample results are within the limits specified below.

Verify, by chemical analysis of the stored ice in at In accordance with least one randomly selected ice basket from each ice the Surveillance condenser bay, that ice bed: Frequency Control

a. Boron concentration is .:: 1800 ppm and S2000 Program ppm; and

b. pH is .:: 9.0 and s 9.5.

SR 3.6.11.6 Visually inspect, for detrimental structural wear, In accordance with cracks, corrosion, or other damage, two ice baskets the Surveillance from each azimuthal group of bays. Frequency Control Program SR 3.6.11.7 ------------------------NOTE-------------------------------------

The chemical analysis may be performed on either the liquid solution or on the resulting ice.

Verify, by chemical analysis, that ice added to the ice Each ice addition condenser meets the boron concentration and pH requirements or SR 3.6.11.5.

Watts Bar - Unit 2 3.6-27 Amendment 36

Ice Condenser Doors 3.6.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and 0.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or C AND not met.

0.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.12.1 Verify all inlet doors indicate closed by the Inlet Door In accordance with Position Monitoring System. the Surveillance Frequency Control Program SR 3.6.12.2 Verify, by visual inspection, each intermediate deck In accordance with door is closed and not impaired by ice, frost, or the Surveillance debris. Frequency Control Program SR 3.6.12.3 Verify, by visual inspection, each inlet door is not 3 months during first impaired by ice, frost, or debris. year after receipt of license In accordance with the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.6-29 Amendment 36

Ice Condenser Doors 3.6.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.12.4 Verify torque required to cause each inlet door to 3 months during first begin to open is ~ 675 in-lb. year after receipt of license In accordance with the Surveillance Frequency Control Program SR 3.6.12.5 Perform a torque test on a sampling of~ 50% of the 3 months during first inlet doors. year after receipt of license In accordance with the Surveillance Frequency Control Program SR 3.6.12.6 Verify for each intermediate deck door: 3 months during first year after receipt of

a. No visual evidence of structural deterioration; license

b. Free movement of the vent assemblies; and

c. Free movement of the door. In accordance with the Surveillance Frequency Control Program SR 3.6.12.7 Verify, by visual inspection; each top deck door: In accordance with the Surveillance

a. Is in place; Frequency Control Program

b. Free movement of top deck vent assembly; and

c. Has no condensation, frost, or ice formed on the door that would restrict its opening.

Watts Bar - Unit 2 3.6-30 Amendment 36

Divider Barrier Integrity 3.6.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.13.1 Verify, by visual inspection, all personnel access Prior to entering doors and equipment hatches between upper and MODE 4from lower containment compartments are closed. MODE5 SR 3.6.13.2 Verify, by visual inspection, that the seals and Prior to final closure sealing surfaces of each personnel access door and after each opening equipment hatch have:

AND

a. No detrimental misalignments;

NOTE---------

b. No cracks or defects in the sealing surfaces; and Only required for seals made of

c. No apparent deterioration of the seal material. resilient materials In accordance with the Surveillance Frequency Control Program SR 3.6.13.3 Verify, by visual inspection, each personnel access After each opening door or equipment hatch that has been opened for personnel transit is closed.

SR 3.6.13.4 Not used SR 3.6.13.5 Visually inspect ~ 95% of the divider barrier seal In accordance with length, and verify: the Surveillance Frequency Control

a. Seal and seal mounting bolts are properly Program installed; and

b. Seal material shows no evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical appearance.

Watts Bar - Unit 2 3.6-32 Amendment 36

Containment Recirculation Drains 3.6.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.14.1 Verify, by visual inspection, that: In accordance with the Surveillance

a. Each refueling canal drain plug is removed; Frequency Control Program

b. Each refueling canal drain is not obstructed by debris; and

c. No debris is present in the upper compartment Prior to entering or refueling canal that could obstruct the MODE 4 from refueling canal drain. MODE 5 after each partial or complete fill of the canal SR 3.6.14.2 Verify for each ice condenser floor drain that the: In accordance with the Surveillance

a. Gate opening is not impaired by ice, frost, or Frequency Control debris; Program

b. Gate seat shows no evidence of damage;

c. Gate opening force is ::;; 100 lb; and

d. Drain line from the ice condenser floor to the lower compartment is unrestricted.

Watts Bar - Unit 2 3.6-34 Amendment 36

Shield Building 3.6.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.15.1 Verify annulus negative pressure is equal to or more In accordance with negative than -5 inches water gauge with respect to the Surveillance the atmosphere. Frequency Control Program SR 3.6.15.2 Verify the door in each access opening is closed, In accordance with except when the access opening is being used for the Surveillance normal transient entry and exit. Frequency Control Program SR 3.6.15.3 Verify shield building structural integrity by During shutdown for performing a visual inspection of the exposed interior SR 3.6.1.1 Type A and exterior surfaces of the Shield Building. tests SR 3.6.15.4 Verify each Emergency Gas Treatment System train In accordance with with final flow ::::: 3600 cfm and :;:; 4400 cfm produces the Surveillance an annulus pressure equal to or more negative Frequency Control than - 0.61 inch water gauge at elevation 783 with Program respect to the atmosphere and with an inleakage of

250 cfm.

Watts Bar - Unit 2 3.6-36 Amendment 36

MSIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -------------------------------NOTE------------------------------

Req u ired to be performed in MODES 1 & 2.

Verify closure time of each MSIV is :s; 6.0 seconds on In accordance with an actual or simulated actuation signal. the lnservice Testing Program or in accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.7-5 Amendment 36

MFIVs and MFRVs and Associated Bypass Valves 3.7.3 ACTIONS (continued)

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

E. One MFIV bypass valve E.1 Restore one MFIV 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and MFRV bypass valve in bypass valve or MFRV the same flow path bypass valve to inoperable. OPERABLE status.

F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND F.2 Be in MODE4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the closure time of each MFIV, MFRV, and In accordance with associated bypass valve is::::: 6.5 seconds on an the lnservice Testing actual or simulated actuation signal. Program or in accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3. 7-7 Amendment 36

ADVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7.4.1 Verify one complete cycle of each ADV. In accordance with the Surveillance Frequency Control Program SR 3.7.4.2 Verify one complete cycle of each ADV block valve. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3. 7-9 Amendment 36

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and In accordance with automatic valve in each water flow path, and in both the Surveillance steam supply flow paths to the steam turbine driven Frequency Control pump, that is not locked, sealed, or otherwise Program secured in position, is in the correct position.

SR 3.7.5.2 ------------------------------NO TE------------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after ~ 1092 psig in the steam generator.

Verify the developed head of each AFW pump at the In accordance with flow test point is greater than or equal to the required the lnservice Testing developed head. Program SR 3.7.5.3 -------------------------------NOTE------------------------------

N ot applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW automatic valve that is not locked, In accordance with sealed, or otherwise secured in position, actuates to the Surveillance the correct position on an actual or simulated Frequency Control actuation signal. Program SR 3.7.5.4 -------------------------------NO TE------------------------------

1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after ~ 1092 psig in the steam generator.

2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program (continued)

Watts Bar - Unit 2 3.7-12 Amendment 36

CST 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is :2: 200,000 gal. In accordance with the Surveillance Frequency Control Program Watts Bar- Unit 2 3.7-15 Amendment 36

ccs 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify that the alternate feeder breaker to the C-S In accordance with pump is open. the Surveillance Frequency Control Program SR 3.7.7.2 -------------------------------NOTE------------------------------

1so Iati on of CCS flow to individual components does not render the CCS inoperable.

Verify each CCS manual, power operated, and In accordance with automatic valve in the flow path servicing safety the Surveillance related equipment, that is not locked, sealed, or Frequency Control otherwise secured in position, is in the correct Program position.

SR 3.7.7.3 Verify each CCS automatic valve in the flow path that In accordance with is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.7.4 ------------------------------NOTE------------------------------

Verification of CCS pump 1 B-B automatic start on SI is not required when CCS pump 1 B-B is supporting CCS Train B OPERABILITY.

Verify each CCS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.7.5 ------------------------------NOTE-----------------------------

Only required to be met when CCS pump 1B-B is supporting CCS Train B OPERABILITY.

Verify CCS pump 1B-B is aligned to CCS Train B and In accordance with is in operation. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.7-17 Amendment 36

ERCW 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ------------------------------NO TE------------------------------

1solation of ERCW flow to individual components does not render the ERCW inoperable.

Verify each ERCW manual, power operated, and In accordance with automatic valve in the flow path servicing safety the Surveillance related equipment, that is not locked, sealed, or Frequency Control otherwise secured in position, is in the correct Program position.

SR 3. 7.8.2 Verify each ERCW automatic valve in the flow path In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.8.3 Verify each ERCW pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program Watts Bar- Unit 2 3.7-19 Amendment 36

UHS 3.7.9

3. 7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)

LCO 3.7.9 The UHS shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS inoperable. A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify average water temperature of UHS is::;;; 85°F. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3. 7-20 Amendment 36

CREVS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Two CREVS trains G.1 Suspend movement of Immediately inoperable in MODE 5 or 6, irradiated fuel or during movement of assemblies.

irradiated fuel assemblies.

OR One or more CREVS trains inoperable due to inoperable CRE boundary in MODE 5 or 6, or during movement of irradiated fuel assemblies.

H. Two CREVS trains H.1 Enter LCO 3.0.3 Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B or E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CREVS train for ~ 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.7.10.2 Perform required CREVS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP (continued)

Watts Bar - Unit 2 3.7-23 Amendment 9, 36

CREVS 3.7.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3. 7.10.3 Verify each CREVS train actuates on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.10.4 Perform required CRE unfiltered air inleakage testing In accordance with in accordance with the Control Room Envelope the Control Room Habitability Program. Envelope Habitability Program Watts Bar - Unit 2 3. 7-23a Amendment 36

CREATCS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7 .11.1 Verify each CREATCS train has the capability to In accordance with remove the assumed heat load. the Surveillance Frequency Control Program Watts Bar - Unit 2 3. 7-25 Amendment 36

ABGTS 3.7.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7.12.1 Operate each ABGTS train for 2 15 continuous In accordance with minutes with the heaters operating. the Surveillance Frequency Control Program SR 3.7.12.2 Perform required ABGTS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.12.3 Verify each ABGTS train actuates on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.12.4 Verify one ABGTS train can maintain a pressure In accordance with between -0.25 inches and -0.5 inches water gauge the Surveillance with respect to atmospheric pressure during the post Frequency Control accident mode of operation at a flow rate Program 2 9300 cfm and :,; 9900 cfm.

Watts Bar - Unit 2 3. 7-27 Amendment 15, 36

Fuel Storage Pool Water Level 3.7.13

3. 7 PLANT SYSTEMS 3.7.13 Fuel Storage Pool Water Level LCO 3.7.13 The fuel storage pool water level shall be :2: 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool water A.1 -------------NO TE------------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the fuel storage pool water level is :2: 23 ft In accordance with above the top of the irradiated fuel assemblies seated the Surveillance in the storage racks. Frequency Control Program Watts Bar - Unit 2 3. 7-28 Amendment 36

Secondary Specific Activity 3.7.14

3. 7 PLANT SYSTEMS 3.7.14 Secondary Specific Activity LCO 3.7.14 The specific activity of the secondary coolant shall be ::::: 0.10 µCi/gm DOSE EQUIVALENT 1-131.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months limit.

AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the specific activity of the secondary coolant is In accordance with

0.10 µCi/gm DOSE EQUIVALENT 1-131. the Surveillance Frequency Control Program Watts Bar - Unit 2 3. 7-29 Amendment 36

CCS - Shutdown 3.7.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify correct breaker alignment and indicated power In accordance available to the required pump(s) that is not in with the operation. Surveillance Frequency Control Program SR 3. 7.16.2 Verify two CCS pumps are aligned to CCS Train B. In accordance with the Surveillance Frequency Control Program Watts Bar-Unit 2 3.7-33 Amendment 36

ERCW - Shutdown 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify correct breaker alignment and indicated In accordance with power available to the required pump(s) that is the Surveillance not in operation. Frequency Control Program Watts Bar-Unit 2 3.7-36 Amendment 36

Fuel Storage Pool Boron Concentration 3.7.18 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.18.1 Verify the fuel storage pool boron concentration is In accordance within limit. with the Surveillance Frequency Control Program Watts Bar-Unit 2 3.7-38 Amendment 27, 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 -------------------------------NOTES----------------------------

1. Performance of SR 3.8.1.7 satisfies this SR.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each DG starts from standby conditions and As specified in achieves steady state voltage 2 6800 V and Table 3.8.1-1

S; 7260 V, and frequency 60 Hz nominal.

SR 3.8.1.3 -------------------------------NOTES----------------------------

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded and As specified in operates for 2 60 minutes at a load Table 3.8.1-1 2 3960 kW and :S; 4400 kW.

(continued)

Watts Bar - Unit 2 3.8-5 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.4 Verify each skid mounted day tank contains In accordance with

~ 218.5 gal offuel oil. the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each In accordance with skid mounted day tank. the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from 7 day storage tank the Surveillance to the skid mounted day tank. Frequency Control Program SR 3.8.1.7 Verify each DG starts from standby condition and In accordance with achieves ins 10 seconds, voltage~ 6800 V, and the Surveillance frequency~ 58.8 Hz. Verify after DG fast start from Frequency Control standby conditions that the DG achieves steady state Program voltage ~ 6800 V and s 7260 V, and frequency

~ 59.8 Hz and s 60.1 Hz.

(continued)

Watts Bar- Unit 2 3.8-6 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.8 ------------------------------NOTES---------------------------

1. For the 2A-A and 2B-B Shutdown Boards, this Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

2. Transfer capability is only required to be met for 6.9kV shutdown boards that require normal and alternate power supplies.

Verify automatic and manual transfer of each In accordance with 6.9 kV shutdown board power supply from the the Surveillance normal offsite circuit to the alternate offsite circuit. Frequency Control Program (continued)

Watts Bar - Unit 2 3.8-6a Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9 -----------------------------NO TES--------------------------

1. For DGs 2A-A and 28-8, this Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor :2: 0.8 and s 0.9.

Verify each DG rejects a load greater than or equal In accordance with to its associated single largest post-accident load, the Surveillance and: Frequency Control Program

a. Following load rejection, the frequency is s 66.75 Hz;

b. Within 3 seconds following load rejection, the voltage is :2: 6555 V and s 7260 V; and

c. Within 4 seconds following load rejection, the frequency is :2: 59.8 Hz and s 60.1 Hz.

SR 3.8.1.10 -------------------------------NOTE------------------------------

For DGs 2A-A and 28-8, this Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor :2: 0.8 and In accordance with s 0.9 does not trip and voltage is maintained the Surveillance s 8880 V during and following a load rejection of Frequency Control

2: 3960 kW and s 4400 kW and Program

2: 2970 kVAR and s 3300 kVAR.

(continued)

Watts Bar - Unit 2 3.8-7 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 ------------------------------NO TE------------------------------

For DGs 2A-A and 28-8, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power In accordance with signal: the Surveillance Frequency Control

a. De-energization of emergency buses; Program

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in

1O seconds,

2. energizes auto-connected shutdown loads through automatic load sequencer,

3. maintains steady state voltage

~ 6800 V and:::: 7260 V,

4. maintains steady state frequency

~ 59.8 Hz and :::; 60.1 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for

~ 5 minutes.

(continued)

Watts Bar - Unit 2 3.8-8 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 -------------------------------NO TE------------------------------

For DGs 2A-A and 28-8, this Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Engineered Safety In accordance with Feature (ESF) actuation signal each Unit 2 DG the Surveillance auto-starts from standby condition and: Frequency Control Program

a. In s 10 seconds after auto-start and during tests, achieves voltage ;;::: 6800 V and frequency

58.8 Hz;

b. After DG fast start from standby conditions the DG achieves steady state voltage

6800 V ands 7260 V, and frequency

59.8 Hz and s 60.1 Hz.

c. Operates for ;;::: 5 minutes;

d. Permanently connected loads remain energized from the offsite power system; and

e. Emergency loads are energized from the offsite power system.

SR 3.8.1.13 ------------------------------NO TE------------------------------

For DGs 2A-A and 28-8, this Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are bypassed on In accordance with automatic or emergency start signal except: the Surveillance Frequency Control

a. Engine overspeed; and Program

b. Generator differential current (continued)

Watts Bar - Unit 2 3.8-9 Amendment 36

AC Sources - Operating

, 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 -------------------------------NOTES---------------------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. For performance of this test in MODE 1, 2, 3 or 4, three DGs must be maintained operable and in a standby condition.

3. Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor In accordance with 2 0.8 ands 0.9 operates for 2 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: the Surveillance Frequency Control

a. For 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 4620 kW and s 4840 kW Program and 2 3465 kVAR ands 3630 kVAR; and

b. For the remaining hours of the test loaded 2 3960 kW and s 4400 kW and 2 2970 kVAR and s 3300 kVAR.

SR 3.8.1.15 -------------------------------NO TES---------------------------

Th is Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 3960 kW and s 4400 kW.

Momentary transients outside of load range do not invalidate this test.

Verify each DG starts and achieves, in s 10 seconds, In accordance with voltage 2 6800 V, and frequency 2 58.8 Hz. Verify the Surveillance after DG fast start from standby conditions that the Frequency Control DG achieves steady state voltage Program 2 6800 V and s 7260 V, and frequency 2 59.8 Hz and s 60.1 Hz.

(continued)

Watts Bar - Unit 2 3.8-10 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 ------------------------------NOTE-----------------------------

For DGs 2A-A and 2B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG: In accordance with the Surveillance

a. Synchronizes with offsite power source while Frequency Control loaded with emergency loads upon a simulated Program restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

SR 3.8.1.17 -------------------------------NOTE------------------------------

For DGs 2A-A and 2B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify, DG 2A-A and 2B-B operating in test mode In accordance with and connected to its bus, an actual or simulated ESF the Surveillance actuation signal overrides the test mode by: Frequency Control Program

a. Returning DG to ready-to-load operation; and

b. Automatically energizing the emergency load from offsite power.

(continued)

Watts Bar - Unit 2 3.8-11 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.18 ------------------------------NOTE------------------------------

For DGs 2A-A and 2B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify the time delay setting for each sequenced load In accordance with block is within limits for each accident condition and the Surveillance non-accident condition load sequence. Frequency Control Program SR 3.8.1.19 -------------------------------NOTE----------------------------

For DGs 2A-A and 2B-B, this Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power In accordance with signal in conjunction with an actual or simulated ESF the Surveillance actuation signal: Frequency Control Program

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in

:.: 10 seconds,

2. energizes auto-connected emergency loads through load sequencer,

3. achieves steady state voltage:

~ 6800 V and : :.: 7260 V,

4. achieves steady state frequency

~ 59.8 Hz and : :.: 60.1 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

(continued)

Watts Bar - Unit 2 3.8-12 Amendment 36

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 Verify during idle operation that any automatic or In accordance with emergency start signal disables the idle start circuitry the Surveillance and commands the engine to full speed. Frequency Control Program SR 3.8.1.21 Verify when started simultaneously from standby In accordance with condition, each DG achieves, ins 10 seconds, the Surveillance voltage ~ 6800 V and frequency~ 58.8 Hz. Verify Frequency Control after DG fast start from standby conditions that the Program DG achieves steady state voltage

~ 6800 V and s 7260 V, and frequency ~ 59.8 Hz and s 60.1 Hz.

SR 3.8.1.22 --------------------------- NOTES -----------------,.-----------

1. For the 28 and 2C Unit Boards, this Surveillance shall not normally be performed in MODE 1 or 2.

However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

2. Transfer capability is only required to be met for 6.9kV Unit Boards that require normal and alternate power supplies.

Verify automatic transfer of each 6.9kV Unit Board In accordance with 1B, 1C, 28 and 2C power supply from the normal the Surveillance power supply to the alternate power supply. Frequency Control Program Watts Bar - Unit 2 3.8-13 Amendment 36

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more DGs with E.1 Restore starting air 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months starting air receiver receiver pressure to pressure < 190 psig and ~ 190 psig.

~ 170 psig.

F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each 7 day fuel oil storage tank contains In accordance with

~ 56,754 gal of fuel. the Surveillance Frequency Control Program SR 3.8.3.2 Verify lubricating oil inventory is ~ 287 gal per In accordance with engine. the Surveillance Frequency Control Program SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil In accordance with are tested in accordance with, and maintained within the Diesel Fuel Oil the limits of, the Diesel Fuel Oil Testing Program. Testing Program (continued)

Watts Bar - Unit 2 3.8-19 Amendment 36

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.3.4 Verify each DG air start receiver pressure is In accordance with

?: 190 psig. the Surveillance Frequency Control Program SR 3.8.3.5 Check for and remove accumulated water from each In accordance with of the four interconnected tanks which constitute the the Surveillance 7 day fuel oil storage tank. Frequency Control Program SR 3.8.3.6 Perform a visual inspection for leaks in the exposed In accordance with fuel oil system piping while the DG is running. the Surveillance Frequency Control Program SR 3.8.3.7 For each of the four interconnected tanks which In accordance with constitute the 7 day fuel oil storage tank: the Surveillance Frequency Control

a. Drain the fuel oil; Program

b. Remove the sediment; and

c. Clean the tank.

Watts Bar - Unit 2 3.8-20 Amendment 36

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify vital battery terminal voltage is greater than or In accordance with equal to the minimum established float voltage. the Surveillance Frequency Control Program SR 3.8.4.2 Verify DG battery terminal voltage is greater than or In accordance with equal to the minimum established float voltage. the Surveillance Frequency Control Program SR 3.8.4.3 Verify for the vital batteries that the alternate feeder In accordance with breakers to each required battery charger are open. the Surveillance Frequency Control Program SR 3.8.4.4 Verify correct breaker alignment and indicated power In accordance with availability for each DG 125 V DC distribution panel the Surveillance and associated battery charger Frequency Control Program SR 3.8.4.5 Verify each vital battery charger is supplies ~ 200 In accordance with amps at greater than or equal to the minimum the Surveillance established float voltage for ~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Frequency Control Program OR Verify each vital battery charger can recharge the battery to the fully charged state within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.

Watts Bar - Unit 2 3.8-23 Amendment 33, 36

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.6 ------------------------------NO TE------------------------------

C red it may be taken for unplanned events that satisfy this SR.

Verify each DG DC battery charger can recharge the In accordance with battery to the fully charged state within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months while the Surveillance supplying the largest combined demands of the Frequency Control various continuous steady state loads, after a battery Program discharge to the bounding design basis event discharge state.

SR 3.8.4.7 -----------------------------NO TES------------------------------

1. The modified performance discharge test in SR 3.8.6.7 may be performed in lieu of the service test in SR 3.8.4.7.

2. This Surveillance is not performed in MODE 1, 2, 3, or 4 for required vital batteries.

Credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required the Surveillance emergency loads and any connected nonsafety loads Frequency Control for the design duty cycle when subjected to a battery Program service test.

Watts Bar - Unit 2 3.8-24 Amendment 33, 36

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 ------~---~-----~--------N()TE------~---~-~---~-----------

Not required to be met when vital battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify each vital battery float current is s 2 amps. In accordance with the Surveillance Frequency Control Program SR 3.8.6.2 -----------------------------N()TE~-----------------~-----------

Not required to be met when DG battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.2.

Verify each DG battery float current is s 1 amp. In accordance with the Surveillance Frequency Control Program SR 3.8.6.3 Verify each required vital battery and each DG In accordance with battery pilot cell float voltage is ;:; 2.07 V. the Surveillance Frequency Control Program SR 3.8.6.4 Verify each required vital battery and each DG In accordance with battery connected cell electrolyte level is greater the Surveillance than or equal to minimum established design limits. Frequency Control Program SR 3.8.6.5 Verify each required vital battery and each DG In accordance with battery pilot cell temperature is greater than or the Surveillance equal to minimum established design limits. Frequency Control Program*

(continued)

Watts Bar - Unit 2 3.8-31 Amendment 33, 36

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.6 Verify each required vital battery and each DG In accordance with battery connected cell float voltage is 2!: 2.07 V. the Surveillance Frequency Control Program SR 3.8.6.7 --~-~----~----------~-~--N()TES------------~----~----------

This Surveillance is not performed in M()DE 1, 2, 3, or 4 for required vital batteries. Credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is ~ 80% of the In accordance with manufacturer's rating when subjected to a the Surveillance performance discharge test or a modified Frequency Control performance discharge test. Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity

~ 100% of manufacturer's rating Watts Bar - Unit 2 3.8-32 Amendment 33, 36

Inverters - Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and In accordance with alignment to required AC vital bus. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.8-34 Amendment 32, 36

Inverters - Shutdown 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and In accordance with alignments to required AC vital bus. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.8-36 Amendment 32, .36

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND G.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. Two trains with one or more H.1 Enter LCO 3.0.3. Immediately inoperable distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance with required AC, vital DC, and AC vital bus electrical the Surveillance power distribution subsystems. Frequency Control Program Watts Bar - Unit 2 3.8-38a Amendment 32, 36

Distribution Systems - Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to restore Immediately required AC, vital DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to In accordance with required AC, vital DC, and AC vital bus electrical the Surveillance power distribution subsystems. Frequency Control Program Watts Bar - Unit 2 3.8-40 Amendment 36

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.

APPLICABILITY: MODE6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS.

AND A.2 Suspend positive Immediately reactivity additions.

AND A.3 Initiate action to restore Immediately boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified In accordance with in COLR. the Surveillance Frequency Control Program Watts Bar- Unit 2 3.9-1 Amendment 36

Unborated Water Source Isolation Valves 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Isolation Valves LCO 3.9.2 Each valve used to isolate unborated water sources shall be secured in the closed position.

APPLICABILITY: MODE6.

ACTIONS

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

Separate Condition entry is allowed for each unborated water source isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. --------------NO TE------------- A.1 Suspend CORE Immediately Required Action A.3 must AL TERATIONS.

be completed whenever Condition A is entered. AND

A.2 Initiate action to secure Immediately One or more valves valve in closed position.

not secured in closed position. AND A.3 Perform SR 3.9.1.1. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water In accordance with sources is secured in the closed position. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.9-2 Amendment 36

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 ------------------------------NO TE-------------------------------

Ne utro n detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Watts Bar - Unit 2 3.9-4 Amendment 36

RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) 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 SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of :c: 2500 gpm. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.9-7 Amendment 36

RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR loop in operation. 8.1 Suspend operations Immediately involving a reduction in reactor coolant boron concentration.

AND 8.2 Initiate action to restore Immediately one RHR loop to operation.

8.3 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 SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of z 2000 gpm. the Surveillance Frequency Control Program SR 3.9.6.2 Verify correct breaker alignment and indicated power In accordance with available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Watts Bar - Unit 2 3.9-9 Amendment 36

Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9. 7 Refueling Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained ~ 23 ft above the top of reactor vessel flange.

APPLICABILITY: During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water level A.1 Suspend movement of Immediately not within limit. irradiated fuel assemblies within containment.

AND A.2 Initiate action to restore Immediately refueling cavity water level to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water level is~ 23 ft above the In accordance with top of reactor vessel flange. the Surveillance Frequency Control Program Watts Bar- Unit 2 3.9-10 Amendment 36

Spent Fuel Pool Boron Concentration 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Spent Fuel Pool Boron Concentration LCO 3.9.9 Boron concentration of the spent fuel pool shall be 2 2300 ppm.

APPLICABILITY: Whenever any fuel assembly is stored in the flooded spent fuel pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A. 1 Initiate action to restore Immediately not within limit. fuel storage pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify boron concentration in the spent fuel pool is In accordance with 2 2300 ppm. the Surveillance Frequency Control Program Watts Bar - Unit 2 3.9-12 Amendment 27, 36

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals 5.7.2.22 Battery Monitoring and Maintenance Program (continued)

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

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

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

5.7.2.23 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

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

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

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

Watts Bar-Unit 2 5.0-27b Amendment 33, 36

SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NOS. 132 AND 36 TO FACILITY OPERATING LICENSE NOS. NPF-90 AND NPF-96 TENNESSEE VALLEY AUTHORITY WATTS BAR NUCLEAR PLANT, UNITS 1 AND 2 DOCKET NOS. 50-390 AND 50-391

1.0 INTRODUCTION

By application dated October 12, 2018 (Reference 1), as supplemented by letters dated May 7, June 6, and August 29, 2019, and January 17, 2020 (References 2, 3, 4, and 5, respectively),

the Tennessee Valley Authority (TVA, the licensee), requested changes to the Watts Bar Nuclear Plant (Watts Bar), Units 1 and 2, Technical Specifications (TSs).

The proposed changes would revise the TSs by relocating specific surveillance requirement (SR) frequencies to a licensee-controlled program in accordance with Nuclear Energy Institute (NEI) 04-10, Revision 1, Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies (Reference 6). The requested changes are consistent with the U.S. NRC-approved Technical Specification Task Force (TSTF) Standard Technical Specifications (STS) Change Traveler TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee ControlRITSTF [Risk-Informed TSTF] Initiative 5b (Reference 7).

The supplemental letters dated May 7, June 6, and August 29, 2019; and January 17, 2020; provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the U.S. Nuclear Regulatory Commission (NRC or the Commission) staffs original proposed no significant hazards consideration determination as published in the Federal Register on April 9, 2019 (84 FR 14152).

2.0 REGULATORY EVALUATION

2.1 Background The licensee proposed to modify the Watts Bar TSs by relocating specific surveillance frequencies to a licensee-controlled program, i.e., the Surveillance Frequency Control Program (SFCP) in accordance with NEI 04-10, Revision 1. The licensee stated that the proposed changes are consistent with the adoption of NRC-approved TSTF-425, Revision 3. The Federal Register notice published on July 6, 2009 (74 FR 31996), announced the availability of TSTF-425, Revision 3. When implemented, TSTF-425, Revision 3, relocates most periodic Enclosure 3

frequencies of TS surveillances to the SFCP, and provides requirements for the new SFCP in the Administrative Controls section of the TSs. All surveillance frequencies can be relocated except the following:

Frequencies that reference other approved programs for the specific interval (such as the Inservice Testing Program or the Primary Containment Leakage Rate Testing Program);

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

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 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).

The licensee proposed to relocate the specific surveillance frequencies documented in the license amendment request from the following TS Sections to the SFCP:

3.1 Reactivity Control System 3.2 Power Distribution Limits 3.3 Instrumentation 3.4 Reactor Coolant System (RCS) 3.5 Emergency Core Cooling Systems (ECCS) 3.6 Containment Systems 3.7 Plant Systems 3.8 Electrical Power Systems 3.9 Refueling Operations The licensee proposed to add the SFCP to TS Section 5.0, Administrative Controls, Subsection 5.7, Procedures, Programs, and Manuals. The SFCP describes the requirements for the program to control changes to the relocated surveillance frequencies. The proposed changes to the Administrative Controls section of the TSs to incorporate the SFCP include a specific reference to NEI 04-10, Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs. The TS Bases for each affected surveillance would be revised to state that the surveillance frequency is controlled under the SFCP.

In a letter dated September 19, 2007 (Reference 8), the NRC staff approved Topical Report NEI 04-10, Revision 1, as acceptable for referencing in licensing actions, to the extent specified and under the limitations delineated in NEI 04-10, Revision 1, and in the NRC staffs safety evaluation for NEI 04-10, Revision 1.

The licensee proposed other changes and deviations from TSTF-425, which are discussed in Section 3.2 of this safety evaluation.

2.2 Applicable Commission Policy Statements In the Final Policy Statement: Technical Specifications for Nuclear Power Plants, dated July 22, 1993 (58 FR 39132), the NRC addressed the use of Probabilistic Safety Analysis (PSA, currently referred to as Probabilistic Risk Assessment, or PRA) in STS. In this 1993 publication, the NRC stated:

The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of Title 10 of the Code of Federal Regulations (10 CFR), Section 50.36] to be deleted from Technical Specifications based solely on PSA (Criterion 4). However, if the results of PSA indicate that Technical Specifications can be relaxed or removed, a deterministic review will be performed.

The Commission Policy in this regard is consistent with its Policy Statement on Safety Goals for the Operation of Nuclear Power Plants, 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, . . . probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made . . .

about the degree of confidence to be given these [probabilistic] estimates and assumptions. This is a key part of the process for determining the degree of regulatory conservatism that may be warranted for particular decisions. This defense-in-depth approach is expected to continue to ensure the protection of public health and safety.

The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line-item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes.

Approximately two years later, the NRC provided additional detail concerning the use of PRA in the Final Policy Statement: Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities, dated August 16, 1995 (60 FR 42622). In this publication, the NRC stated:

The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRCs deterministic approach. . . .

PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common cause failures. The treatment therefore goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by considering risk in a more coherent and complete manner. . . .

Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commissions intention to encourage the use of PRA and to expand the scope of PRA applications in all nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data. . . .

Therefore, the Commission adopts the following policy statement regarding the expanded NRC use of PRA:

(1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRCs deterministic approach and supports the NRCs traditional defense-in-depth philosophy.

(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with 10 CFR 50.109 (Backfit Rule).

Appropriate procedures for including PRA in the process for changing regulatory requirements should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised.

(3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review.

(4) The Commissions safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees.

2.3 Applicable Regulations In 10 CFR 50.36, Technical Specifications, the NRC established its regulatory requirements related to the content of TSs. Pursuant to 10 CFR 50.36, TSs are required to include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation; (3) surveillance requirements (SRs); (4) design features; and (5) administrative controls. These categories will remain in the Watts Bar, Units 1 and 2, TSs.

Section 50.36(c)(3) of 10 CFR states, [s]urveillance requirements are requirements relating to test, calibration, or inspection 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. The Federal Register notice published on July 6, 2009 (74 FR 31996),

which announced the availability of TSTF-425, Revision 3, states that the addition of the SFCP

to the TSs provides the necessary administrative controls to require that surveillance frequencies relocated to the SFCP 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. The FR notice also states that changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, Revision 1, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and are required to be documented.

Existing regulatory requirements, such as 10 CFR 50.65, Requirements for monitoring the effectiveness of maintenance at nuclear power plants (i.e., the Maintenance Rule), and 10 CFR Part 50, Domestic Licensing of Production and Utilization Facilities, Appendix B, Criterion XVI, Corrective Action, require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. Such failures can result in the licensee increasing the frequency of a surveillance test. In addition, by having the TSs require that changes to the frequencies listed in the SFCP be made in accordance with NEI 04-10, Revision 1, the licensee will be required to monitor the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs.

2.4 Applicable NRC Guidance Regulatory Guide (RG) 1.174, Revision 3, An Approach for Using Probabilistic Risk Assessment in Risk Informed Decisions on Plant-Specific Changes to the Licensing Basis (Reference 9), describes an acceptable risk-informed approach for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk insights. This RG also provides risk acceptance guidelines for evaluating the results of such evaluations.

RG 1.177, Revision 1, An Approach for Plant-Specific, Risk-Informed Decisionmaking:

Technical Specifications (Reference 10), describes an acceptable risk informed approach specifically for assessing proposed TS changes.

RG 1.200, Revision 2, An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities (Reference 11), describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light-water reactors (LWRs).

NUREG-1431, Standard Technical Specifications, Westinghouse Plants, Volume 1, Revision 4.0 (Reference 12) and Standard Technical Specifications, Westinghouse Plants, Volume 2, Bases, Revision 4.0 (Reference 13), respectively contain the improved STS for Westinghouse plants. The improved STS were developed based on the criteria in the Final Commission Policy Statement of Technical Specifications Improvements for Nuclear Power Reactors, dated July 22, 1993 (58 FR 39132), which was subsequently codified by changes to 10 CFR 50.36 (60 FR 36953).

3.0 TECHNICAL EVALUATION

TVAs adoption of TSTF-425, Revision 3, provides for Watts Bar, Units 1 and 2 administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to

the administrative controls of TS. TSTF-425, Revision 3, also requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. The licensees application for the changes proposed in TSTF-425, Revision 3, included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200, Revision 2, Section 4.2. In accordance with NEI 04-10, Revision 1, PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.174, Revision 3 and RG 1.177, Revision 1, in support of changes to surveillance test intervals.

3.1. RG 1.177 Five Key Safety Principles RG 1.177, Revision 1, identifies five key principles required for risk-informed changes to TS.

Each of these principles is addressed by the industry methodology document, NEI 04-10, Revision 1.

3.1.1. The Proposed Change Meets Current Regulations The regulations in 10 CFR 50.36(c)(3) provide that TSs will include surveillances which are requirements relating to test, calibration, or inspection to assure that 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. NEI 04-10 provides guidance for relocating the surveillance frequencies from the TSs to a licensee-controlled program by providing an NRC-approved methodology for control of the surveillance frequencies. The surveillances themselves would remain in the TSs, as required by 10 CFR 50.36(c)(3).

This change is consistent with other NRC-approved TS changes in which the surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-service Testing Program or the Primary Containment Leakage Rate Testing Program. Further the NEI 04-10, Revision 1, guidance provides for monitoring the performance of SSCs for which surveillance frequencies are decreased to assure that the reduced testing does not adversely impact the SSCs. Thus, this proposed change meets the current regulations for monitoring surveillance test failures and implementing corrective actions to address such failures, in accordance with 10 CFR 50.65 and 10 CFR Part 50, Appendix B, Criterion XVI, Corrective Action.

Therefore, this proposed change meets the first key principle of RG 1.177, Revision 1, by complying with current regulations.

3.1.2. The Proposed Change Is Consistent with the Defense-in-Depth Philosophy Consistency with the defense-in- depth philosophy, the second key principle of RG 1.177, Revision 1, is maintained if:

A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.

Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.

System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., no risk outliers). Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.

Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.

Independence of barriers is not degraded.

Defenses against human errors are preserved.

The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained.

TSTF-425, Revision 3, requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. NEI 04-10, Revision 1, uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.174, Revision 3 and RG 1.177, Revision 1, for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes including contributions from human errors and common cause failures. Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to increased likelihood of common cause failures. Both the quantitative risk analysis and the qualitative considerations assure a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, satisfying the second key principle of RG 1.177, Revision 1.

3.1.3. The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change with the principle that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure sufficient safety margin will continue to exist.

The design, operation, testing methods, and acceptance criteria for SSCs, specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the Updated Final Safety Analysis Report and TS Bases), since these are not affected by changes to the surveillance frequencies.

Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis.

Thus, safety margins are maintained by the proposed methodology, and the third key principle of RG 1.177, Revision 1, is satisfied.

3.1.4. When Proposed Changes Result in an Increase in Core Damage Frequency or Risk, the Increases Should Be Small and Consistent with the Intent of the Commissions Safety Goal Policy Statement RG 1.177, Revision 1, provides a framework for evaluation of the risk of proposed changes to surveillance frequencies, which requires identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425, Revision 3, requires application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1, satisfies the intent of RG 1.177, Revision 1, requirements for evaluation of the change in risk, and for assuring that such changes are small. Thus, TVAs proposed relocation of specific surveillance frequencies to the SFCP in accordance with NEI 04-10, Revision 1, and TSTF-425, Revision 3, satisfies the fourth key principle of RG 1.177, Revision 1.

3.1.4.1 Quality of PRA The acceptability of TVAs PRA is compatible with the safety implications of the proposed TS change and the role the PRA plays in justifying the change. That is, the more the potential change in risk or the greater the uncertainty in that risk that results from the requested TS change, or both, the greater the rigor that must go into ensuring the acceptability of the PRA.

TVA used RG 1.200, Revision 2, to address the plant PRA technical acceptability for this application. RG 1.200, Revision 2, provides regulatory guidance for assessing the technical acceptability of a PRA and endorses (with clarifications and qualifications) the use of the American Society of Mechanical Engineers/American Nuclear Society (ASME/ANS) PRA standard ASME/ANS RA-Sa-2009, Addenda to ASME RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications (Reference 14), NEI 00-02, Probabilistic Risk Assessment Peer Review Process guidelines (Reference 15) and NEI 05-04, Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard (Reference 16). The licensee has performed an assessment of the PRA models used to support the SFCP against the requirements of RG 1.200, Revision 2, to assure that the PRA models, using plant specific data and models, are capable of determining the change in risk due to changes to surveillance frequencies of SSCs. Capability Category II (CC II) of ASME/ANS RA-Sa-2009 is required by NEI 04-10, and any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including the use of sensitivity studies, as appropriate. This level of PRA acceptability is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP and is consistent with regulatory position 2.3.1 of RG 1.177, Revision 1.

Internal Events and Internal Flooding PRA Upon implementation of the SFCP, TVA will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out.

The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency.

Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, Revision 2, and by

sensitivity studies identified in NEI 04-10, Revision 1. TVA will perform quantitative evaluations of the impact of selected testing strategy (i.e., staggered testing or sequential testing) consistent with the guidance of NUREG/CR-6141 and NUREG/CR-5497, as discussed in NEI 04-10, Revision 1.

Thus, through the application of NEI 04-10, Revision 1, TVAs PRA modeling process is sufficient to ensure the performance of an acceptable evaluation of risk for the proposed changes in surveillance frequency and is consistent with regulatory position 2.3.3 of RG 1.177, Revision 2. The NRC staff reviewed Table 6 of Attachment 3 to the license amendment request, which summarized the peer review team assessment of the Watts Bar PRA models that do not conform to CC II of the ASME PRA standard Supporting Requirements. The NRC staffs assessment of these open finding level Facts and Observations (F&Os), the impacted Supporting Requirements, and TVAs resolutions concluded that they are addressed and dispositioned for this application per the NEI 04-10 guidance, as discussed below.

F&O 1-6, associated with Supporting Requirement DA-D3, was generated because both mean and error factor values were produced for each type code for the Bayesian update process used for Watts Bar. However, it was noted that uncertainty interval data was not entered into the PRA software database file and that extraneous information from previous versions of the database were being applied to the factor (demands or exposure time) field of the basic event table. TVA performed a sensitivity analysis that identified the missing uncertainty parameters for common-cause failure (CCF) events (and dependent human error probability (HEP) events) and replaced the parameters with representative uncertainty parameters in the software databases. The NRC staff finds this resolution acceptable for the application because the licensee eliminated the gap in the analysis.

F&O 2-28, associated with Supporting Requirements HR-D5, HR-G7, QU-C1, and QU-C2 was generated because some of the combined operator action probabilities were below the threshold specified in the notebook. The concern was over human errors following test or maintenance because these error probabilities have a direct impact and risks associated with changing surveillance frequencies. The recovery files, which define the dependent HEPs were reviewed to determine if they included any pre-initiator HEPs. The recovery files had no pre-initiator HEPs; therefore, TVA concluded that the dependent HEPs do not include pre-initiator HEPs. Given that the dependent HEPs do not contain pre-initiator HEPs, the NRC staff finds there is no impact on surveillance test interval (STI) calculations.

F&O 3-6, associated with Supporting Requirements QU-A3 and QU-E3, was generated because the results of the parametric uncertainty analysis did not include the uncertainty parameters for the CCF events and Interfacing System Loss of Coolant Accident (ISLOCA) events. In addition, the human reliability analysis dependency recovery events found in the recovery files are not treated properly in the parametric uncertainty analysis. There was no parametric uncertainty assessment nor State of Knowledge Correlation (SOKC) used. Because there was a potential for underestimating the ISLOCA contribution, the Watts Bar PRA will be updated including a SOKC for ISLOCA. In its letter dated May 7, 2019, the licensee provided a commitment to update the updated model of record prior to making any STI changes.

F&O 5-8, associated with Supporting Requirements LE-C2, LE-C7, LE-C9, and LE-E1, was generated because the operator action failure probabilities considered in the LERF analysis were not correctly estimated. After core damage, the operation steps in the SAMGs would be much different from the steps in the Emergency Operating Procedures before core damage.

This finding addresses over-conservatisms with respect to operator actions that were not

credited following the onset of core damage. The SFCP process for extending an STI is not affected by the issue discussed in this finding because the STI evaluation determines the change in risk and the uncredited actions will affect similarly the original and the extended interval risk with little or no impact on the change in risk. Therefore, NRC staff finds that the change in risk would not be expected to be significantly impacted by modeling the aforementioned operator actions.

F&O 7-10, associated with Supporting Requirement IFQU-A6, was generated because the analysis for the internal flooding related human actions seemed to exclude actions outside the main control room given a flood event and made little, if any, adjustment to the other actions that were performed in the main control room. TVA addressed the question by providing a tabulation and evaluation of flood-related human failure events taking less than or equal to one-hour for diagnosis and action, and their corresponding impact. As a result, the NRC staff finds that F&O 8-10 would be expected to have a negligible impact on STI calculations.

F&O 7-21, associated with Supporting Requirement IFEV-B3 was generated because the range factors were developed for the flood initiating events, however there was no propagation through the model. TVA performed an investigation for those flooding initiators that grouped multiple systems and/or pipe sizes into a single initiating event to determine the suitability of the assigned uncertainty parameters. The investigation concluded that the error factors assigned to these initiators adequately represent the uncertainties associated with the distributions that represent the subject flooding initiator frequencies. Tables of Flooding Initiator Error Factors were provided by TVA. The modified error factors do not result in a significant change to the calculated mean values. As a result, the NRC staff finds that changing the error factor assignments would be expected to have a negligible impact on STI calculations.

F&O 7-22, associated with Supporting Requirement LE-D5, was generated because the secondary side isolation of a ruptured steam generator was modeled in the Steam Generator Tube Rupture event tree. After core damage, there was no consideration of the secondary side isolation capability in the accident progression sequences. This finding addresses a conservatism with respect to not crediting secondary side isolation capability. The SFCP process for extending an STI is not affected by the issue discussed in this finding because the STI evaluation determines the change in risk and the uncredited actions will affect similarly the original and the extended interval risk with little or no impact on the change in risk. Therefore, the NRC staff finds the change in risk would not be expected to be significantly impacted by modeling the secondary side isolation capability.

Seismic PRA In Attachment 2 to the license amendment request, TVA stated that its SFCP would use a seismic PRA (SPRA). Sections 2.5.1, 2.5.2, and 2.5.3 of Attachment 2 to the license amendment request discussed the SPRA peer review, SPRA F&O independent assessment closure review, and open SPRA peer review finding-level F&Os. The NRC staffs review of the technical acceptability of the SPRA for this application is discussed below. During the review of this license amendment request, the NRC staff utilized information from TVAs submittal in response to the 10 CFR 50.54(f) information request arising from Near Term Task Force recommendation 2.1 (Reference 17), the supplement to that submittal dated April 10, 2018 (Reference 18), and the corresponding NRC staff response letter dated July 10, 2018 (Reference 19).

The NRC staff reviewed the results of the peer review process for the SPRA presented in Section 2.5 of Attachment 2 to the license amendment request. The licensee stated that the SPRA was developed using a full-scope peer review against all technical elements in Part 5, Requirements for Seismic Events At-Power PRA of ASME/ANS RA-Sb-2013 PRA Standard, Addenda to ASME/ANS RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications (Reference 20) and in accordance with NEI 12-13, External Hazards PRA Peer Review Process Guidelines, (Reference 21). RG 1.200, Revision 2, endorses ASME/ANS RA-Sa-2009, which is also known as Addendum A of the PRA Standard. The licensees SPRA peer review was performed using the SPRA requirements in ASME/ANS RA-Sb-2013, also known as Addendum B of the Standard. RG 1.200, Revision 2, does not endorse Addendum B, as noted in a July 6, 2011, letter from the NRC staff to the ASME (Reference 22). Request for additional Information (RAI)

APLB-02 requested TVA to demonstrate that the Supporting Requirements in Part 5 of Addendum B are consistent with those in Addendum A. In response to RAI APLB-02 in its supplement dated May 7, 2019, TVA stated that it performed an assessment consistent with the information in Southern Nuclear Operating Company (SNC), Inc., letter to NRC, NL-17-1201, (Reference 23). TVA stated that Tables 1, 2, and 3 of the assessment in SNC letter NL-17-1201 to the NRC were incorporated by reference by TVA for this application and supplemented by licensee-specific information for Supporting Requirements SHA-B3, SHA-C3, SFR-C3, SFR-C6, SFR-G3, and SPR-B1. The licensee-specific information for the above-mentioned Supporting Requirements provided the basis for TVAs assessment that for those Supporting Requirements, the licensees SPRA model development conformed to Addendum A.

The NRC staff has previously accepted the assessment in Tables 1, 2, and 3 of the assessment in SNC letter NL-17-1201 to the NRC, as documented in the staffs letter to SNC dated August 10, 2018 (Reference 24). Because the licensee incorporated by reference the assessment in SNC letter NL-17-1201 to the NRC for its SPRA, the NRC staffs acceptance of SNCs assessment is valid for TVAs SPRA for this application. Based on the above, the NRC staff finds that TVA has appropriately assessed its SPRA against the cited Supporting Requirements for this application.

Based on the NRC staffs review of TVAs discussion in Section 2.5 of Attachment 2 of the submittal and the licensees comparison of Supporting Requirements of Part 5 of Addendum B of the PRA Standard compared to those in Addendum A in its response to RAI APLB-02, the NRC staff finds that TVAs use of Addendum B to be an acceptable alternative to the NRC-endorsed approach for this application because it adequately addresses the technical elements for the development of a SPRA.

Step 5 of NEI 04-10, Revision 1 states that the PRA used for the licensees SFCP must be of sufficient technical capability and be subjected to a peer review process assessed against a standard or set of acceptance criteria that is endorsed by NRC RG 1.200, Revision 2.

RAI APLB-01 requested the licensee to discuss how the SPRA peer review and independent assessment team F&O closure review considered the NRC staffs comments in the March 7, 2018, acceptance letter documenting the NRC staffs acceptance of NEI 12-13 and provide justification for not considering specific comments. In response to RAI APLB-01, TVA provided descriptions on how it met the NRC staffs clarifications and qualifications on NEI 12-13 in the March 7, 2018 letter. The licensees response to the 10 CFR 50.54(f) letter, dated June 30, 2017, included, in Section A.2.2 of Appendix A of that submittal, information regarding the qualifications of each Watts Bar SPRA peer reviewer. The information in Section A.2.2 also stated that the peer reviewers met the independence criteria in NEI 12-13.

Based on the information provided by TVA in response to RAI APLB-01, as well as the information available in Section A.3 of Appendix A of the licensees response to the

10 CFR 50.54(f) letter, the NRC staff finds the licensees response acceptable for this application because it adequately addresses the qualifications and independence of the SPRA peer review team in the context of Watts Bar SPRA.

Unreviewed Analysis Methods are a specific type of F&O assigned by peer reviewers and are defined in Section 3.2 of NEI 12-13. The NRC staff provided comments on NEI 12-13 related to F&Os for Unreviewed Analysis Methods and new methods encountered during a peer-review.

In response to RAI APLB-01, TVA stated that the SPRA peer-review team did not identify any new methods in the licensees SPRA. As a result, further details regarding any new methods and a corresponding staff review to determine their acceptability for this application are unnecessary. Therefore, the staff finds the licensees response to RAI-APLB-01 to be acceptable for this application because it addresses the issue of Unreviewed Analysis Methods and new methods in the Watts Bar SPRA.

In response to RAI APLB-01, the licensee stated the internal events PRA peer review findings closure assessment report indicated that 43 of the 50 internal events PRA findings were assessed to be closed and that the Watts Bar SPRA peer review report indicated that a review of the results and conclusions of the internal events PRA peer review and considerations of potential impact on the SPRA was performed as part of the SPRA peer review, consistent with the guidance in Section 1.4 of NEI 12-13. The NRC staff notes that in its supplement to the 10 CFR 50.54(f) submittal dated April 10, 2018, the licensee confirmed that the model that was reviewed in the closure review is the same model that was used as the basis for the Watts Bar SPRA and, therefore six of the seven internal events PRA F&Os have no impact on the Watts Bar SPRA. The licensee also confirmed in its supplement dated May 7, 2019, that internal events PRA F&O 3-6 remained open because the SOKC was not applied in the Interfacing Systems LOCA calculation of valve failure properties but did not affect the SPRA model because similar components were grouped into fragility groups that were completely correlated. The NRC staffs review of the information in the supplement to the 10 CFR 50.54(f) submittal and the disposition of the internal events PRA F&Os finds that the open internal events PRA F&Os do not impact the SPRA model. The licensee also stated that the Watts Bar SPRA was reviewed against CC II of the PRA Standard for all applicable Supporting Requirements and that any Supporting Requirements that the reviewers found to meet only CC I had associated finding-level F&Os. The NRC staff notes that Table A.1 in Appendix A of licensees response to the 10 CFR 50.54(f) letter, dated June 30, 2017, shows findings for Supporting Requirements met at CC I were closed utilizing the independent assessment team closure review process. Based on its review, the NRC staff finds that the SPRA peer review was performed to CC II of the PRA Standard, which is acceptable to support the staffs determination of technical acceptability of the SPRA for this application and any Supporting Requirements found to meet only CC I had associated findings.

The Watts Bar SPRA independent assessment F&O closure review reviewed the 74 finding-level F&Os from the SPRA peer review and determined that all but one was resolved, and therefore, closed. In its response to RAI APLB-01, the licensee stated that although the Watts Bar SPRA independent assessment F&O closure was performed prior to the publication of the NRC letter accepting the process, the NRC staffs expectations in the letter were addressed in the report of the independent assessment F&O closure review, which was completed in July 2017. The NRC staff notes that, in its supplement to the 10 CFR 50.54(f) submittal dated April 10, 2018, the licensee confirmed that the independent F&O closure review adhered to the guidance in Appendix X of NEI 12-13 and the two conditions spelled out in the NRC acceptance letter dated May 3, 2017. In that supplement, the licensee explained that cases in which the F&O closure review assessment dispositions were identical to the original

F&O dispositions, the F&O closure reviewers were in full agreement with the original F&O disposition. The licensee also stated in its response to RAI APLB-01 that the review team did not identify the use of any new methods in the resolutions of findings within the review scope nor did they identify any resolutions of the findings within the review scope as upgrades.

One remaining finding-level F&O, F&O 20-5, related to Supporting Requirement SHA-I1, from the SPRA peer-review that was partially resolved and not closed was provided in Attachment 2, Table 8 of the license amendment request, along with its disposition for this application. The NRC staff reviewed this F&O to determine its impact on this application. The F&O was related to screening of seismic failure of upstream dams. The peer review team determined that the licensee had not adequately screened for the seismic failure of upstream dams in its analysis.

Subsequently, the licensee included a screening analysis in its SPRA and considered the F&O to be technically resolved, as discussed in Attachment 2, Section 2.5.3 of the license amendment request. The NRC staff finds that TVAs disposition for F&O 20-5 related to Supporting Requirement SHA-I1 is acceptable for this application because the F&O does not impact this application. The NRC staff also notes that this topic was considered in the NRC staffs review of flooding hazard at Watts Bar, as documented in the staffs interim assessment dated December 1, 2015 (Reference 25).

In the licensees submittal in response to the 10 CFR 50.54(f) letter, TVA stated that seismic failure of SSCs that are inherently rugged and consequently have a very low probability of failing as a result of a seismic event were not included in the SPRA. Step 8 of NEI 04-10, Revision 1 discusses considerations for SSCs that are not evaluated in the SPRA. In response to RAI APLB-04 in the May 7, 2019, supplement, TVA stated that the NEI 04-10, Revision 1 process would be followed for SSCs that were not evaluated in the SPRA, either explicitly or implicitly. The licensee explained that an analyst would determine whether the SSCs associated with the surveillance test(s) were adequately included in the SPRA and if the associated equipment could be modeled, then the SFCP model would be revised to reflect those SSCs. For those SSCs that could not be adequately modeled, a qualitative or bounding analysis would be performed, in accordance with the process outlined in NEI 04-10, Revision 1, Step 10. The NRC staff notes that inherently rugged SSCs have a high capacity and therefore, are expected to have an insignificant impact on the results from a SPRA. The NRC staff finds that the licensees approach for SSCs that are inherently rugged or are not implicitly or explicitly evaluated in the SPRA is acceptable for this application because the approach is consistent with NEI 04-10, Revision 1 guidance and the NRC staffs safety evaluation on the guidance.

In the licensees response to the 10 CFR 50.54(f) letter, TVA stated that the permanently installed Flexible and Diverse Coping Strategies (FLEX) diesel generators were credited in its SPRA. The NRC staffs memorandum dated May 30, 2017 (Reference 26), provides the staffs assessment of challenges to incorporating FLEX equipment and strategies into a PRA model in support of risk-informed decision making, in accordance with the guidance of RG 1.200, Revision 2. RAI APLB-05 requested the licensee to discuss the methodology used to assess the failure probabilities of FLEX equipment and perform the human reliability analysis for FLEX actions credited in the SPRA. The NRC staff also requested the licensee to discuss any existing or planned programmatic elements, which would be taken to ensure that the data assumptions for the FLEX equipment credited in the SPRA would continue to remain valid during the implementation of the licensees SFCP per NEI 04-10, Revision 1, Step 19. In its response to RAI APLB-05 in the May 7, 2019 supplement, the licensee stated that the SPRA credited the permanently installed FLEX diesel generators and their supporting equipment including fuel tank, breaker alignment, buses, and operator actions, were modeled similarly to other internal event PRA components, including development of data, and operator actions (i.e.,

equipment failure probabilities were assumed to be the same as other components of the same type already included in the model). The licensee stated that its SPRA followed the guidance of the ASME/ANS PRA standard in crediting the permanently installed FLEX diesel generators.

The licensee also stated that portable FLEX equipment was not included in the PRA models and that a separate HEP for each FLEX DG was used because the method to start and align the diesel generators was different. The licensee further stated that the FLEX diesel generators were identified as an uncertainty and would be subjected to a sensitivity analysis when applicable for the STI extension under consideration. The licensee stated that its periodic assessment process was performed in accordance with the guidance in NEI 04-10, Revision 1, Step 19, which includes periodic re-assessment with updates to the PRA model. The NRC staff finds the licensees inclusion of FLEX equipment and actions in its SPRA is acceptable for this application because the inclusion is in accordance with the endorsed PRA standard, the permanently installed FLEX diesel generators would be subjected to a sensitivity analysis for the STI extension, and the periodic assessment process is performed in accordance with the guidance in NEI 04-10, Revision 1.

Conclusion Based on its review, the NRC staff concludes that the licensees internal events PRA, including internal flooding, and SPRA are technically acceptable to support the evaluation of changes proposed to surveillance frequencies within the SFCP using the process in NEI 04-10, Revision 1, and is consistent with regulatory position 2.3.1 of RG 1.177, Revision 1.

3.1.4.2. Scope of the PRA Upon implementation of the SFCP, TVA would be required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10, Revision 1, to determine its potential impact on risk, due to impacts from internal events, fires, seismic, other external events, and from shutdown conditions. Consideration is made of both CDF and LERF metrics.

Watts Bar has full-power internal events, including internal floods, as well as SPRA models.

These models received peer reviews as discussed below in Section 3.1.4.1 of this safety evaluation. In accordance with NEI 04-10, Revision 1, TVA will use these models to perform quantitative evaluations to support the development of changes to surveillance frequencies in the SFCP. This is acceptable because the NRC-approved methodology in NEI 04-10, Revision 1, allows for more refined analysis to be performed to support changes to surveillance frequencies in the SFCP.

Watts Bar does not have PRA models for internal fires. However, TVA performed a Fire Induced Vulnerability Evaluation (FIVE) for Watt Bar Units 1 and 2, in response to Individual Plant Examination of External Events (IPEEE), GL 88-20, Supplement 4 (Reference 27). TVA performed its FIVE for Watts Bar, Units 1 and 2 in accordance with EPRI TR-100370 (Reference 28). TVA will assess the impacts on fire risk of an STI extension using a qualitative or a bounding approach supplemented with insights from the IPEEE FIVE analysis and the internal events PRA model. The is consistent with the guidance in NEI 04-10, Revision 1.

Watts Bar does not have PRA models for high winds, tornadoes, external floods, transportation and nearby facility accidents, or other external hazards. For high winds and tornadoes, SSCs important to safety were designed to withstand the design basis tornado and remain functional.

TVA also stated that its procedures provided instructions for actions to be taken in the event of a

tornado watch or a tornado warning near the site and that these actions further mitigated the potential consequences of such an event. TVA explained that external flooding due to upstream dam failures and maximum potential participation was reevaluated since the analysis performed for the IPEEE, and that enhancements were made to the upstream dam, as well as other plant modifications to limit the impact on the plant due to external floods. TVA stated that for the external flooding scenario that exceeded plant grade, over 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months warning was available and that plant procedures were in place to respond to a flood warning within 27 hours3.125e-4 days 0.0075 hours 4.464286e-5 weeks 1.02735e-5 months . TVA further stated that transportation and nearby facility accidents evaluation of potential accidents concluded that no activities were being performed in the plant vicinity that could be considered hazardous to the plant, and other external hazards were assessed in the IPEEE. In accordance with NEI 04-10, Revision 1, the licensee can perform an initial qualitative screening analysis, and, if the qualitative information is not sufficient to provide confidence that the net impact of the STI change would be negligible, a bounding analysis will be performed. TVA stated that its approach will use a qualitative process, and bounding analyses where appropriate, for assessing the risk impact of extending the surveillance frequency on SSCs for non-PRA modeled hazards, such as, internal fire risk, non-seismic external hazards (e.g., high winds and external flooding), and shutdown events.

The NRC staff finds that high winds and tornadoes, external flooding, and other external hazards do not significantly impact this application. This is because of 1) the plants robust design, procedures, and enhancements and 2) the licensees approach for considering any impact is consistent with the guidance in NEI 04-10, Revision 1, and the staffs safety evaluation on the guidance. In cases where a PRA of sufficient scope or where quantitative risk models were unavailable, TVA uses bounding analyses, or other conservative quantitative evaluations consistent with NEI 04-10.

The licensee stated that for assessing the shutdown risk, it will use the shutdown risk management program for implementation of Nuclear Management and Resources Council 91-06 (Reference 29) for the proposed changes to surveillance frequencies under the SFCP. This is an acceptable approach in accordance with NEI 04-10, Revision 1.

Thus, the NRC staff finds that TVAs evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation and is consistent with regulatory position 2.3.2 of RG 1.177, Revision 1.

3.1.4.3. PRA Modeling Consistent with NEI 04-10, Revision 1, upon implementation of the SFCP, TVA will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to surveillance frequency.

Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, Revision 2, and by sensitivity studies identified in NEI 04-10, Revision 1.

TVA will perform quantitative evaluations of the impact of selected testing strategy (i.e.,

staggered testing or sequential testing) consistently with the guidance of NUREG/CR-6141 (Reference 30) and NUREG/CR-5497 (Reference 31), as discussed in NEI 04-10 Revision 1.

Thus, through the application of NEI 04-10, Revision 1, TVAs PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency and is consistent with regulatory position 2.3.3 of RG 1.177, Revision 1.

3.1.4.4. Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in TVAs PRAs assume all failures to be time-related because the breakdown between standby time-related contribution and a cyclic demand-related contribution is unknown. NEI 04-10, Revision 1, criteria adjust the time-related failure contribution of SSCs affected by the proposed change to a surveillance frequency. This is consistent with Section 2.3.3 of RG 1.177, Revision 1, which permits separation of the failure rate contributions into demand and standby for evaluation of Supporting Requirements.

According to the guidance in NEI 04-10, Revision 1, if the available data do not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. The process requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. Thus, the process is not reliant upon risk analyses as the sole basis for the proposed changes.

The potential beneficial risk impacts of reduced surveillance frequency, including reduced downtime, lesser potential for restoration errors, reduction of potential for test caused transients, and reduced test-caused wear of equipment, are identified qualitatively, but are conservatively not required to be quantitatively assessed.

Thus, through the application of NEI 04-10, Revision 1, TVA has employed reasonable assumptions with regard to extensions of surveillance test intervals and is consistent with regulatory position 2.3.4 of RG 1.177, Revision 1.

3.1.4.5. Sensitivity and Uncertainty Analyses NEI 04-10, Revision 1, requires sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact to the frequency of initiating events, and of any identified deviations from CC II of ASME PRA Standard (ASME RA-Sb-2009). Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies.

Guidance in Step 5 of NEI 04-10, Revision 1 specifies risk sensitivity studies to be conducted by changing the unavailability terms for PRA basic events that correspond to SSCs being evaluated. The approach for identification of key assumptions and sources of uncertainty was unclear. In response to RAI APLB-03 in its May 7, 2019, supplement, the licensee stated that assumptions and sources of uncertainty related to the seismic hazard development, fragility analyses, and plant response model were not characterized as key in Section 2.5.5 of of the license amendment request. The licensee also stated that for each STI considered for extension, assumptions and sources of uncertainty of the SPRA applicable to the STI extension would be reviewed to identify those that are key. The licensee further explained

that for the identified key assumptions, consistent with the process described in NEI 04-10, Revision 1, their impact on the risk insights as well as sensitivity studies would be performed to ensure there was no undue reliance on key assumptions and causes of uncertainty. The NRC staffs safety evaluation on NEI 04-10, Revision 1, dated September 19, 2007, stated that the guidance in NEI 04-10, Revision 1 appropriately considers the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations. Based on its review, the NRC staff finds the licensees response to RAI APLB-03 to be acceptable for this application because the licensees approach for key assumptions and sources of uncertainty, and the consideration of their potential impact on this application is consistent with the NEI 04-10, Revision 1 guidance and the NRC staffs finding on that topic in the staffs safety evaluation of NEI 04-10, Revision 1.

Consistent with NEI 04-10, Revision 1, required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. Thus, through the application of NEI 04-10, Revision 1, TVA has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, consistently with regulatory position 2.3.5 of RG 1.177, Revision 1.

3.1.4.6. Acceptance Guidelines TVA will quantitatively evaluate the change in total risk (including internal and external events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NEI 04-10, as required in the SFCP.

Each individual change to surveillance frequency must show a risk impact below 10-6 per year for change to CDF, and below 10-7 per year for change to LERF. These are consistent with the limits of RG 1.174, Revision 3, for very small changes in risk. Where the RG 1.174, Revision 3, limits are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.174, Revision 3, or the process terminates without permitting the proposed changes. Where quantitative results are unavailable to permit comparison to acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to the surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.174, Revision 3, acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact below 10-5 per year for change to CDF, and below 10-6 per year for change to LERF, and the total CDF and total LERF must be reasonably shown to be less than 10-4 per year and 10-5 per year, respectively. These are consistent with the limits of RG 1.174 for acceptable changes in risk, as referenced by RG 1.177, Revision 1, for changes to surveillance frequencies.

Consistent with the NRCs safety evaluation for NEI 04-10, Revision 1, dated September 19, 2007, the SFCP will require TVA to calculate the change in risk from a baseline model utilizing failure probabilities based on the surveillance frequencies prior to implementation of the SFCP, compared to a revised model with failure probabilities based on changed surveillance frequencies. The NRC staff notes that TVAs SFCP includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than 5 x 10-8 CDF and 5 x 10-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies.

The quantitative acceptance guidance of RG 1.174, Revision 3, is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history. The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results compared to numerical acceptance guidelines. Post-implementation performance monitoring and feedback are also required to assure continued reliability of the components.

The licensees application of NEI 04-10, Revision 1, provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177, Revision 1. Therefore, the proposed TVA methodology satisfies the fourth key safety principle of RG 1.177, Revision 1, by assuring any increase in risk is small consistent with the intent of the Commissions Safety Goal Policy Statement.

3.1.5. The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies TVAs adoption of TSTF-425, Revision 3, requires application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Rev.1, requires performance monitoring of SSCs whose surveillance frequency has been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety.

The monitoring and feedback includes consideration of maintenance rule monitoring of equipment performance. In the event of a degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may apply as part of the maintenance rule requirements. The performance monitoring and feedback specified in NEI 04-10, Revision 1, is sufficient to reasonably assure acceptable SSC performance and is consistent with regulatory position 3.2 of RG 1.177, Revision 1.

Thus, the fifth key safety principle of RG 1.177, Revision 1 is satisfied.

3.2. Deviations From TSTF-425 and Other Changes In Sections 2.2.1 and 2.2.2 of the license amendment request, as supplemented, TVA identified variations and technical changes from the TSTF-425 template. The NRC staffs evaluation of those changes is below.

The licensee stated that Watts Bar SRs have numbers that differ from the corresponding Westinghouse STSs surveillances, have wording that is slightly different, and have differing existing frequencies with a similar testing intent. The licensee considers the deviations to be administrative. The NRC staff evaluated this deviation and determined that it is administrative in nature. Therefore, the NRC staff finds this deviation to be acceptable.

The licensee stated that for NUREG-1431 surveillances that are not in the Watts Bar TS (including where a Watts Bar SR frequency is ineligible for control under the SFCP), the corresponding NUREG-1431 mark-ups in TSTF-425 are not applicable to Watts Bar.

The NRC staff evaluated the deviation and determined that it is administrative in nature.

Therefore, the NRC staff finds this deviation to be acceptable.

The licensee stated that various TSTF-425 Section 3.3 instrumentation surveillances are invoked by instrumentation functions contained in tables. The analogous Watts Bar surveillances may have different SR numbers, slightly different wording, and may be invoked by a different set of functions. The NRC staff evaluated this deviation and determined that it is administrative in nature. Therefore, the NRC staff finds this deviation to be acceptable.

The licensee stated that various Watts Bar Unit 1 surveillances include one-time, historical requirements not depicted on the TSTF-425 markup. While these are not being removed from the Watts Bar Unit 1 TS, they are nonetheless considered to be administrative variations from TSTF-425. The NRC staff evaluated the deviation and determined that it is administrative in nature. Therefore, the NRC staff finds this deviation to be acceptable.

The licensee identified several Watts Bar plant-specific SRs with fixed periodic frequencies that are not contained in NUREG-1431, and therefore, are not included in TSTF-425. The licensee assessed these SRs and determined that the relocation of the frequencies for these SRs is consistent with TSTF-425. The licensee requested that these Surveillances be controlled under the SFCP.

The SFCP provides administrative controls to require that surveillances related to testing, calibration, and inspection are conducted at a frequency to assure that the necessary quality of the systems and components is maintained, the facility operation will be within safety limits, and that the LCOs will be met. The SFCP requires that changes to the frequencies be evaluated using the methodology and probabilistic risk guidelines contained in NEI 04-10, Revision 1, as approved by NRC letter dated September 19, 2007. The NEI 04-10, Revision 1, methodology includes qualitative considerations, risk analyses, sensitivity studies, and bounding analyses, as necessary, and recommended monitoring of the performance of SSCs for which frequencies are changed to assure that reduced testing does not adversely impact the SSCs.

The NRC staff evaluated the proposed deviations for the identified plant-specific TS SRs listed in Attachment 7 of the license amendment request and determined that the SR frequencies do not meet any of the exclusion criteria in TSTF-425, Revision 3, and that the frequencies are fixed periodic frequencies. Therefore, the NRC staff finds that relocation of these plant-specific TS SR frequencies to the SFCP is acceptable.

The licensee proposed to replace the TS Bases insert, The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program, which is provided in TSTF-425.

The proposed new text would read, The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

In a letter dated April 14, 2010 (Reference 32), the NRC staff agreed that the insert applies to surveillance frequencies that are relocated and subsequently evaluated and changed in accordance with the SFCP, but does not apply to frequencies relocated to the SFCP, but not changed. The NRC staff reviewed the proposed wording and determined that this is an administrative deviation only and is therefore acceptable.

The licensee made various formatting changes, such as revising the footers of various pages in the TS markups to promote consistency, inserting new pages due to text rollover, and punctuation corrections on affected SRs. The NRC staff reviewed the changes and determined that they are administrative in nature and are therefore acceptable.

The licensee proposed to change the frequency of Watts Bar SR 3.7.5.2, which has a current frequency of 31 days on a Staggered Test Basis. The proposed frequency would change to a frequency of In accordance with the Inservice Testing Program.

The licensee provided justification for this change stating, Watts Bar SR 3.7.5.2 correlates to NUREG-1431 STS SR 3.7.5.2; however, the STS frequency is controlled in accordance with the Inservice Testing Program. That change was made to the STS with TSTF-101 (Reference 33).

The NRC staff reviewed the proposed change and determined that it continues to meet the frequency requirements for SR 3.7.5.2. SR 3.7.5.2 testing is currently required as part of the Watts Bar Inservice Testing Program. The Inservice Testing Program for Watts Bar provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program includes testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants. For these reasons, the NRC staff finds the proposed change to the SR 3.7.5.2 Frequency acceptable.

3.3. Addition of Surveillance Frequency Control Program to TS Section 5 TVA has included the SFCP and specific requirements into TS Section 5, Administrative Controls, Section 5.7.2.21, as follows:

This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure that the associated Limiting Conditions for Operation are met.

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

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

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

The proposed program is consistent with the model application of TSTF-425 and, therefore, the NRC staff concludes that it is acceptable.

3.4 Summary and Technical Conclusions The NRC staff has reviewed TVAs proposed relocation of certain surveillance frequencies to a licensee-controlled document and its proposed control of changes to surveillance frequencies in

accordance with a new program, the SFCP, identified in the administrative controls of the TSs.

The SFCP and TS Section 5.7.2.21 reference NEI 04-10, Revision 1, which provides a risk-informed methodology using plant- specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from the TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10, Revision 1, which is specified in the administrative controls of the TS.

The proposed adoption by TVA of TSTF-425, Revision 3, and risk-informed methodology of NEI 04-10, Revision 1, as referenced in the administrative controls of TS, satisfies the key principles of risk-informed decision making applied to changes to TS as delineated in RG 1.177, Revision 1 and RG 1.174, Revision 3, in that:

The proposed change meets current regulations; The proposed change is consistent with defense-in-depth philosophy; The proposed change maintains sufficient safety margins; Increases in risk resulting from the proposed change are small and consistent with the Commissions Safety Goal Policy Statement; and The impact of the proposed change is performance monitoring using measurement strategies.

10 CFR 50.36(c)(3) states Technical specifications will include items in the following categories: Surveillance Requirements. Surveillance Requirements are requirements relating to test, calibration, or inspection 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. The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, TVA continues to meet the regulatory requirement of 10 CFR 50.36, and specifically, 10 CFR 50.36(c)(3), Surveillance Requirements.

The NRC has concluded, on the basis of the considerations discussed above, that (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the NRCs regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public.

4.0 STATE CONSULTATION

In accordance with the Commissions regulations, the Tennessee State official was notified of the proposed issuance of the amendment on January 10, 2020. The State official stated that the State saw no significant variations or deviations from the current TVA program in these proposed amendments. As such, the State believes that no changes should be made to the Division of Radiological Healths current environmental monitoring and emergency response programs.

5.0 ENVIRONMENTAL CONSIDERATION

The amendments change a requirement with respect to installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20, Standards for Protection Against Radiation, and/or changes SRs. The NRC staff has determined that the amendments involve no significant increase in the amounts, and no significant change in the types, of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission previously issued a proposed finding that the amendment involves no significant hazards consideration, in the Federal Register on April 9, 2019 (84 FR 14152), and there has been no public comment on such finding published. Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

6.0 CONCLUSION

The Commission has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commissions regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

7.0 REFERENCES

1. Henderson, E. K., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Application for Technical Specifications Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (WBN-TS-18-14), October 12, 2018 (Agency Documents Access and Management System (ADAMS) Accession No. ML18288A352).

2. Henderson, E. K., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Response to Request for Additional Information Regarding Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (WBN-TS-18-14) (EPID L-2018-LLA-0279), May 7, 2019 (ADAMS Accession No. ML19127A323).

3. Henderson, E. K., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Correction to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (WBN-TS-18-14) (EPID L-2018-LLA-0279), June 6, 2019 (ADAMS Accession No. ML19157A302).

4. Polickoski, J.T., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Supplement to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (WBN-TS-18-14) (EPID L-2018-LLA-0279),

August 29, 2019 (ADAMS Accession No. ML19242D967).

5. Polickoski, J. T., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Second Supplement to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (WBN-TS-18-14) (EPID L-2018-LLA-0279) January 17, 2020 (ADAMS Accession No. ML20017A303).

6. Nuclear Energy Institute, Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies, NEI 04-10, Revision 1, April 2007 (ADAMS Accession Number ML071360456).

7. Technical Specification Task Force to U.S. Nuclear Regulatory Commission, Transmittal of TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b, March 18, 2009 (ADAMS Accession No. ML090850642).

8. Nieh, H. K., U.S. Nuclear Regulatory Commission, to B. Bradley, Nuclear Energy Institute, Final Safety Evaluation for Nuclear Energy Institute (NEI) Topical Report (TR) 04-10, Revision 1, Risk-Informed Technical Specification Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies (TAC NO. MD6111),

September 19, 2007 (ADAMS Accession No. ML072570267).

9. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.174, Revision 3, An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis, January 2018 (ADAMS Accession No. ML17317A256).

10. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.177, Revision 1, An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications, May 2011 (ADAMS Accession No. ML100910008).

11. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.200, Revision 2, An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities, March 2009 (ADAMS Accession No. ML090410014).

12. U.S. Nuclear Regulatory Commission, NUREG-1431, Revision 4, Volume 1, Standard Technical Specifications - Westinghouse Plants, April 2012 (ADAMS Accession No. ML12100A222)

13. U.S. Nuclear Regulatory Commission, NUREG-1431, Revision 4, Volume 2, Standard Technical Specifications - Westinghouse Plants, April 2012 (ADAMS Accession No. ML12100A228).

14. American Society of Mechanical Engineers, ASME/ANS RA-Sa-2009, Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications, Addendum A to RA-S-2008, February 2009.

15. Nuclear Energy Institute, NEI 00-02, Probabilistic Risk Assessment (PRA) Peer Review Process Guidance, March 2000 (ADAMS Accession No. ML003728023).

16. Nuclear Energy Institute, NEI 05-04, Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard, August 2006.

17. Shea, J. W., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Seismic Probabilistic Risk Assessment for Watts Bar Nuclear Plant, Units 1 and 2 -

Response to NRC Request for Information Pursuant to Title 10 of the Code of Federal Regulations 50.54(f) Regarding Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident, June 30, 2017 (ADAMS Accession No. ML17181A485).

18. Shea, J. W., Tennessee Valley Authority to U.S. Nuclear Regulatory Commission, Tennessee Valley Authority (TVA) - Watts Bar Nuclear Plant Seismic Probabilistic Risk Assessment Supplemental Information, April 10, 2018 (ADAMS Accession No. ML18100A966).

19. Lund, L., U.S. Nuclear Regulatory Commission to Shea, J. W., Tennessee Valley Authority, Watts Bar Nuclear Plant, Units 1 And 2 - Staff Review of Seismic Probabilistic Risk Assessment Associated With Reevaluated Seismic Hazard Implementation of The Near-Term Task Force Recommendation 2.1: Seismic (CAC Nos. MF9879 and MF9880; EPID L-2017-JLD-0044), July 10, 2018 (ADAMS Accession No. ML18115A138).

20. American Society of Mechanical Engineers, ASME/ANS RA-Sb-2013, Addenda to ASME/ANS RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications, July 2013.

21. Nuclear Energy Institute, NEI 12-13, External Hazards PRA Peer Review Process Guidelines, August 2012 (ADAMS Accession No. ML12240A027).

22. Correria, R., U.S. Nuclear Regulatory Commission to Martinez, O., American Society of Mechanical Engineers, U.S. Nuclear Regulatory Commission (NRC) Comments on Addenda to A Current ANS: ASME RA-SB - 20xx, Standard For Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications, July 6, 2011 (ADAMS Accession No. ML111720067).

23. Hutto, J. J., Southern Nuclear Operating Company, to U.S. Nuclear Regulatory Commission, Vogtle Electric Generating Plant Units 1 and 2 Response to Supplemental Information Needed for Acceptance of Systematic Risk-Informed Assessment of Debris Technical Report, NL-17-1201, July 11, 2017 (ADAMS Accession No. ML17192A245).

24. Orenak, M., U.S. Nuclear Regulatory Commission, to Gayheart, C., Southern Nuclear Operating Company, Vogtle Electric Generating Plant, Units 1 and 2 - Issuance of Amendments Regarding Application of Seismic Probabilistic Assessment into the Previously Approved 10 CFR 50.69 Categorization Process (EPID L-2017-LLA-0248),

August 10, 2018 (ADAMS Accession No. ML18180A062).

25. Uribe, J., U.S. Nuclear Regulatory Commission, to Shea, J. W., Tennesse Valley Authority, Watts Bar Nuclear Plant, Units 1 And 2 - Staff Assessment of Response to Request for Information Pursuant to 10 CFR 50.54(f) Flood-Causing Mechanisms Reevaluation (TAC Nos. MF5857 and MF5858), December 1, 2015 (ADAMS Accession No. ML15310A085).

26. Reisi-Fard, M., U.S. Nuclear Regulatory Commission, to Giitter, J., U.S. Nuclear Regulatory Commission, Assessment of the Nuclear Energy Institute 16-06, Crediting

Mitigating Strategies in Risk-Informed Decision Making, Guidance for Risk-Informed Changes to Plants Licensing Basis, May 30, 2017 (ADAMS Accession No. ML17031A269).

27. U.S. Nuclear Regulatory Commission, Generic Letter No. 88-20, Supplement 4, Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities - 10 CFR 50.54(f), June 28, 1991 (ADAMS Accession No. ML031150485).

28. Electric Power Research Institute, TR-100370, Fire-Induced Vulnerability Evaluation (FIVE), September 1993.

29. Nuclear Management Resources Council, NUMARC 91-06, Guidelines for Industry Actions to Assess Shutdown Management, December 1991 (ADAMS Accession No. ML14365A203).

30. U.S. Nuclear Regulatory Commission, NUREG/CR-6141, Handbook of Methods for Risk-Based Analyses of Technical Specifications, December 1994 (ADAMS Accession No. ML093090361).

31. U.S. Nuclear Regulatory Commission, NUREG/CR-5497, Common-Cause Failure Parameter Estimations, October 1998.

32. Bowman, Eric E., U.S. Nuclear Regulatory Commission, to Technical Specifications Task Force, Notification of Issue with NRC-Approved Technical Specifications Task Force (TSTF) Traveler TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b, April 14, 2010 (ADAMS Accession No. ML100990099).

33. Technical Specifications Task Force, TSTF-101, Change AFW Pump Testing Frequency to be In Accordance with the Inservice Testing Program, April 2, 1998 (ADAMS Accession No. ML040480072).

Principal Contributors: Jeff Circle Tarico Sweat Keith Tetter Date: February 28, 2020

ML20028F733 *by e-mail OFFICE NRR/DORL/LPL2-2/PM NRR/DORL/LPL2-2/LA NRR/DRA/APLA/BC NAME MWentzel BAbeywickrama SRosenberg DATE 02/07/2020 02/04/2020 07/16/2019 OFFICE NRR/DRA/APLB/TL(A) NRR/DSS/STSB/BC* NRR/DE/ECIB/BC*

NAME SVasavada VCusumano MWaters DATE 07/16/2019 01/08/2020 02/03/2020 OFFICE NRR/DE/EEOB/BC* NRR/DSS/SNSB(A)* OGC (NLO)

NAME BTitus JBorromeo DRoth DATE 01/28/2020 01/29/2020 02/19/2020 OFFICE NRR/DORL/LPL2-2/BC NRR/DORL/LPL2-2/PM NAME UShoop (GEMiller for) MWentzel DATE 02/28/2020 02/28/2020

v t e Letter Sequence Approval
EPID:L-2018-LLA-0279, TSTF-425 (Approved, Closed)
Initiation Request, Request, Request Acceptance... Supplement, Supplement Administration Questions 8 March 2019 5 August 2019 Answers Results Approval, Approval Other:
MONTHYEAR2019-07-25 [Table View]

ML20028F733

Text

SUBJECT:

Dear Mr. Barstow:

Enclosures:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

4.0 STATE CONSULTATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 CONCLUSION

7.0 REFERENCES

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