ML15301A140

Watts Bar, Unit 2, Current Facility Operating License NPF-96, Tech Specs, Revised 11/08/2017

ML15301A140
Person / Time
Site:	Watts Bar
Issue date:	10/22/2015
From:	Dean W M Division of Operating Reactor Licensing
To:	Tennessee Valley Authority
Boska J P
References
Download: ML15301A140 (390)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 TENNESSEE VALLEY AUTHORITY DOCKET NO. 50-391 WATTS BAR NUCLEAR PLANT, UNIT 2 FACILITY OPERATING LICENSE License No. NPF-96 1. The Nuclear Regulatory Commission (the Commission or the NRC) has found that: A. The application for an operating license filed by the Tennessee Valley Authority (TVA, the licensee) complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I, and all required notifications to other agencies or bodies have been duly made; B. Construction of the Watts Bar Nuclear Plant, Unit 2 (the facility) has been substantially completed in conformity with Construction Permit No. CPPR-92 and the application, as amended, the provisions of the Act and the rules and regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission; D. There is reasonable assurance (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 1 O CFR Chapter I; E. TVA is technically qualified to engage in the activities authorized by this license in accordance with the Commission's regulations set forth in 1 O CFR Chapter I; F. TVA has satisfied the applicable provisions of 1 O CFR Part 140, "Financial Protection Requirements and Indemnity Agreements;"

G. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental,

economic, technical and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Facility Operating License No. NPF-96, subject to the conditions for protection of the environment set forth in the Environmental Protection Plan attached as Appendix B, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and I. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 1 O CFR Parts 30, 40, and 70. 2. Based on the foregoing findings regarding this facility, Facility Operating License No. NPF-96 is hereby issued to TVA to read as follows:

A. This license applies to the Watts Bar Nuclear Plant, Unit 2, a pressurized water reactor and associated equipment (the facility) owned by TV A. The facility is located on the west bank of the Chickamauga Lake on TVA's site in Rhea County, Tennessee, and is described in TVA's Final Safety Analysis Report, as supplemented and amended up to Amendment No. 114 and in the Final Environmental Statement, Watts Bar Nuclear Plant Units 1 and 2, as supplemented and amended; B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses TVA: (1) Pursuant to Section 103 of the Act and 1 O CFR Part 50, to possess, use, and operate the facility at the designated location in Rhea County, Tennessee, in accordance with the procedures and limitations set forth in this license; (2) Pursuant to the Act and 1 O CFR Part 70, to receive,

possess, and use at any time, special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, and as. described in the Final Safety Analysis Report, as supplemented and amended; (3) Pursuant to the Act and 1 O CFR Parts 30, 40 and 70, to receive,

possess, and use at any time, any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) 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) Pursuant to the Act and 1 O CFR Parts 30 and 70, to possess but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

Unit 2 C. The license shall be deemed to contain and is subject to the conditions specified in the Commission's 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. 19 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 for Cycles 1 and 2 only. PAD4TCD may not be used to establish core operating limits for subsequent reload cycles. (5) By December 31, 2017, 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:

Facility License No. NPF-96 Amendment No. 19 TVA may make changes to the approved fire protection program without prior approval of the Commission, only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire. (9) By May 31, 2018, TVA shall report that a listing organization acceptable to the NRG (as the Authority Having Jurisdiction) has determined that the fire detection monitoring panel in the main control room either meets the appropriate designated standards or has been tested and found suitable for the specified purpose.

(10) TVA will verify for each core reload that the actions taken if Faw(Z) is not within limits will assure that the limits on core power peaking Fa(Z) remain below the initial total peaking factor assumed in the accident analyses.

(11) TVA will implement the compensatory measures described in Section 3.4, "Additional Compensatory Measures,"

of TV A letter CNL-18-012, dated January 17, 2018, during the timeframe the temperature indicator for RCS hot leg 3 is not required to be operable for the remainder of Cycle 2. If the RCS hot leg 3 temperature indicator is returned to operable status prior to the end of Cycle 2, then these compensatory measures are no longer required.

D. The licensee shall have and maintain financial protection of such types and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims. F. This license is effective as of the date of issuance and shall expire at midnight on October 21, 2055. Appendices:

1. Appendix A -FOR THE NUCLEAR REGULATORY COMMISSION original signed by William M. Dean, Director Office of Nuclear Reactor Regulation Technical Specifications

2. Appendix B -Environmental Protection Plan Date of Issuance:

October 22, 2015 Amendment No. 19

(F)

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCO 3.0.2 LCO 3.0.3 LCO 3.0.4 Watts Bar -Unit 2 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2, 3.0.7, and 3.0.8. Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6. If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s),

completion of the Required Action(s) is not required unless otherwise stated. When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable.

Action shall be initiated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, in: a. MODE 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />; b. MODE 4 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />; and c. MODE 5 within 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br />. Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4. When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made: a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; (continued) 3.0-1 Amendment 6

LCO Applicability 3.0 3.0 APPLICABILITY (continued)

LCO 3.0.7 LCO 3.0.8 Watts Bar-Unit 2 Test Exception LCO 3.1.9 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations.

Unless otherwise specified, all other TS requirements remain unchanged.

Compliance with Test Exception LCOs is optional.

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

When one or more required snubbers are unable to perform their associated support function(s),

any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; or b. the snubbers not able to perform their associated support function{s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. At the end of the specified period, the required snubbers must be able to perform their associated support function(s),

or the affected supported system LCO(s) shall be declared not met. 3.0-3 Amendment 6 I SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SR 3.0.2 SR 3.0.3 Watts Bar -Unit 2 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits. The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met. In addition, for each of the SRs listed in Table SR 3.0.2-1 the specified Frequency is met if the Surveillance is performed on or before the date listed on Table SR 3.0.2-1.

This extension of the test intervals for these SRs is permitted on a one-time basis to be completed no later than November 30, 2017. For Frequencies specified as "once," the above interval extension does not apply. If a Completion Time requires periodic performance on a "once per ... " basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or up to the limit of the specified Frequency, whichever is greater.

This delay period is permitted to allow performance of the Surveillance.

A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

3.0-4 (continued)

Amendment 3, 12 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.3 (continued)

SR 3.0.4 Watts Bar -Unit 2 When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4. This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. 3.0-5 Amendment No. 3 I SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Table SR 3.0.2-1 Frequency Surveillance Requirement (SR) Description of SR Requirement Extension Limit Perform TADOT of the Safety Injection (SI) Input from 10/31/17 3.3.1.13, Table3.3.1-1, Function 15 Engineered Safety Feature Actuation System to Reactor Trip Function 3.3.2.5, Table 3.3.2-1, Function 1.b Perform SLAVE RELAY TEST of the Safety Injection Automatic Actuation Logic and Actuation Relays Function 10/31/17 3.3.2.5, Table 3.3.2-1, Function

2. rm SLAVE RELAY TEST of the Containment Spray 10/31/17 matic Actuation Logic and Actuation Relays Function rm SLAVE RELAY TEST of the Containment Isolation 10/31/17 3.3.2.5, Table 3.3.2-1, Function 3.a(2) Phase A Isolation Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Containment Isolation 10/31/17 3.3.2.5, Table 3.3.2-1, Function 3.b(2} Phase B Isolation Automatic Actuation Logic and Actuation Relavs Function 3.3.2.5, Table 3.3.2-1, Function 4.b Perform SLAVE RELAY TEST of the Steam Line Isolation 10/31/17 Automatic Actuation Loaic and Actuation Relays Function Perform SLAVE RELAY TEST of the Turbine Trip and 10/31/17 3.3.2.5, Table 3.3.2-1, Function 5.a Feedwater Isolation Automatic Actuation Logic and Actuation Relays Function

.

RELAY TEST of the Auxiliary Feedwater 3.3.2.5, Table 3.3.2-1, Function 6*a atic Actuation Loaic and Actuation Relays Function 10/31/17 3.3.2.5, Table 3.3.2-1, Function 7.a 3.3.2.7, Table 3.3.2-1, Function 1.b 3.3.2.7, Table 3.3.2-1, Function 3.a(2) 3.3.2.7, Table 3.3.2-1, Function 3.b(2) 3.3.2.8, Table 3.3.2-1, Function 1.a 3.3.2.8, Table 3.3.2-1, Function 2.a 3.3.2.8, Table 3.3.2-1, Function 3.a(1) 3.3.2.8, Table 3.3.2-1, Function 3.b(1) 3.3.2.10, Table 3.3.2-1, Function 1.c 3.3.2.10, Table 3.3.2-1, Function 1.d 3.3.2.10, Table 3.3.2-1, Function 1.e 3.3.2.10, Table 3.3.2-1, Function 2.c 3.3.2.10, Table 3.3.2-1, Function 3.b(3} Watts Bar Unit 2 Perform SLAVE RELAY TEST of the Automatic Switchover 10/31/17 to Containment Sump Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Safety Injection 10/31/17 Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Containment Isolation 10/31/17 Phase A Isolation Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Containment Isolation 10/31 /17 Phase B Isolation Automatic Actuation Logic and Actuation Relavs Function Perform TADOT of the Safety Injection Manual Initiation 10/31/17 Function Perform TADOT of the Containment Spray Manual 10/31/17 Initiation Function Perform TADOT of the Containment Isolation Phase A Isolation Manual Initiation Function 10/31/17 Perform TADOT of the Containment Isolation Phase B 10/31/17 Isolation Manual Initiation Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Safety Injection Containment Pressure

-High Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Safety Injection Pressurizer Pressure

-Low Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Safety Injection Steam Line Pressure

-Low Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Containment Pressure

-High High Function Verify ESFAS RESPONSE TIMES are within limit for the Containment Isolation Phase B Isolation Containment 10/31/17 Pressure

-High High Function 3.0-6 (continued)

Amendment No. 3, 10, 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.3.2.10, Table 3.3.2-1, Function 6.b 3.3.2.10, Table 3.3.2-1, Function 6.e 3.3.2.10, Table 3.3.2-1, Function 7.b 3.3.3.2, Table 3.3.3-1, Function 5 3.3.3.2, Table 3.3.3-1, Function 6 3.:3.3.3, Table 3.3.3-1, Function 11 3.3.4.2, Table 3.3.4-1, Function 2.b 3.3.4.2, Table 3.3.4-1, Function 2.c 3.:3.4.2, Table 3.3.4-1, Function 3.b Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify ESFAS RESPONSE TIMES are within limit for the Auxiliary Feedwater SG Water Level -Low Low Coincident with: 1) Vessel !J. T Equivalent to power:;;;

50% RTP With a time delay (Ts) if one SG is affected or A time 10/31 /17 delay (Tm) if two or more SGs are affected OR 2) Vessel !J.T equivalent to power> 50% RTP with no time delay (Ts and Tm = 0) Function Verify ESFAS RESPONSE TIMES are within limit for the Auxiliary Feedwater Trip of all Turbine Driven Main 10/31/17 Feedwater Pumps Function Verify ESFAS RESPONSE TIMES are within limit for the Automatic Switchover to Containment Sump Refueling Water Storage Tank (RWST) Level Low Coincident with 10/31/17 Safety Injection and Coincident with Containment Sump Level -High Function Perform CHANNEL CALIBRATION of the RCS Pressur 1/17 (Wide Range) Function Perform CHANNEL CALIBRATION of the Reactor Vessel 10/31/17 Water Level Function Perform TADOT of the Containment Isolation Valve 10/31/17 Position Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Reactor Coolant System (RCS) Pressure Control Pressurizer 10/31/17 Power Operated Relief Valve (PORV) Control and Pressurizer Block Valve Control Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Reactor 10/31/17 Coolant System (RCS) Pressure Control Pressurizer Heater Control Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Reactor 10/31/17 Coolant System (RCS) Pressure Control Pressurizer Heater Control Function 3.0-7 (continued)

Amendment No. 10, 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.3.4.2, Table 3.3.4-1, Function 4.b 3.3.4.2, Table 3.3.4-1, Function 4.c 3.3.4.2, Table 3.3.4-1, Function 5.a 3.3.4.3, Table 3.3.4-1, Function 2.b 3.3.4.3, Table 3.3.4-1, Function 2.c 3.3.4.3, Table 3.3.4-1, Function 4.c 3.3.4.3, Table 3.3.4-1, Function 4.e 3.3.6.5, Table 3.3.6-1, Function 2 3.3.6.6, Table 3.3.6-1, Function 1 3.4.12.8 3.5.2.5 3.5.2.6 3.6.3.6 3.6.6.3 Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify each required control circuit and transfer switch is capable of performing the intended function for the Decay 10131117 Heat Removal via Steam Generators (SGs) AFW Controls Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Decay 10/31/17 Heat Removal via Steam Generators (SGs) SG Pressure Indication and Control Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Decay 10/31/17 Heat Removal via RHR System RHR Flow Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Reactor Coolant System (RCS) Pressure Control Pressurizer Power Operated Relief 10131/17 Valve (PORV) Control and Pressurizer Block Valve Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Reactor Coolant System 10131/17 (RCS) Pressure Control Pressurizer Heater Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Decay Heat Removal via 10/31/17 Steam Generators (SGs) SG Pressure Indication and Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Decay Heat Removal via 10/31117 Steam Generators (SGs) SG Tsat Indication Function Perform SLAVE RELAY TEST of the Containment Vent 10/31/17 Isolation Instrumentation Automatic Actuation Logic and Actuation Relays Function Perform TADOT of the Containment Vent Isolation 10/31/17 Instrumentation Manual Initiation Function Perform CHANNEL CALIBRATION for each required 10/31/17 PORV actuation channel Verify each ECCS automatic valve in the flow path that is 10/31/17 not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each ECCS pump starts automatically on an actual 10/31 /17 or simulated actuation signal. Verify each automatic containment isolation valve that is 10/31/17 not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal Verify each automatic containment spray valve in the flow 10/31/17 path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation sianal 3.0-8 (continued)

Amendment No. 12, 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.6.6.4 3.6.9.3 3.6.11.2 3.6.11.3 3.6.13.5 3.7.7.3 3.7.7.4 3.7.8.2 3.7.8.3 Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify each containment spray pump starts automatically 10/31/17 on an actual or simulated actuation signal Verify each Emergency Gas Treatment System (EGTS) train actuates on an actual or simulated actuation signal 10/31/17 Verify total weight of stored ice is greater than or equal to 2,404,500 lb by: a. Weighing a representative sample of 144 ice baskets and verifying each basket contains greater than or equal 10/31/17 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.

Verify azimuthal distribution of ice at a 95 percent confidence level by subdividing

weights, as determined by SR 3.6.11.2.a, into the following groups: a. Group 1-bays 1 through 8; b. Group 2-bays 9 through 16; and 10/31 /17 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. Visually 95% of the divider barrier seal length, 10/31/17 and verify: a. Seal and seal mounting bolts are properly installed; and b. Seal material shows no evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical aooearance Verify each Component Cooling System (CCS) automatic 10/31/17 valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation sional Verify each CCS pump starts automatically on an actual or 10/31/17 simulated actuation sianal Verify each Essential Raw Cooling Water (ERCW) 10/31/17 automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation sianal Verify each ERCW pump starts automatically on an actual 10/31/17 or simulated actuation signal 3.0-9 (continued)

Amendment 12, 13, 14 3.0 SR APPLICABILITY Surveillance Requirement (SR) 3.8.1.9 3.8.110 3.8. 1. 11 3.8.1.12 3.8.1.13 Watts Bar -Unit 2 SR Applicability 3.0 Table SR 3.0.2-1 Frequency

. Description of SR Requirement Extension Limit Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is s 66.75 Hz; b. Within 3 seconds following load rejection, the voltage is 11/30/17 6555 V and s 7260 V; and c. Within 4 seconds following load rejection, the frequency 59.8 Hz and s 60.1 Hz. Verify each DG operating at a power 0.8 ands 0.9 does not trip and voltage is maintained s 8880 V during 11/30/17 and following a load rejection 3960 kW and s 4400 kW and 2970 kVAR ands 3300 kVAR Verify on an actual or simulated loss of offsite power signal: 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 s 10 seconds,

2. energizes auto-connected shutdown loads through 11/30/17 automatic load sequencer,

3. maintains steady state voltage 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 5 minutes Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each Unit 2 DG auto-starts from standby condition and: 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 11/30/17 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. Verify each DG's automatic trips are bypassed on automatic or emergency start signal except: 11/30/17

a. Engine overspeed; and b. Generator differential current 3.0-10 (continued)

Amendment No. 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.81.16 3.8.1.17 3.8.1.18 3.8.1.19 5.7.2.4b Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite 11 /30/17 power; b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation Verify, DG 2A-A and 2B-B operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and 11/30/17

b. Automatically energizing the emergency load from offsite power. Verify the time delay setting for each sequenced load block is within limits for each accident condition and non-accident 11/30/17 condition load sequence.

Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: 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 s1 O seconds, 11/30/17

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

3. achieves steady state voltage:

?>: 6800 V and s 7260 V, 4. achieves steady state frequency

?>: 59.8 Hz and s 60.1 Hz, and 5. supplies permanently connected and auto-connected emergency loads for?>: 5 minutes.

Perform integrated leak test for each system at least once per 18 months. Specifically, only the centrifugal charging 10/31 /17 pump injection portion of the safety injection system 3.0-11 (continued)

Amendment No. 13

FFF FF F

F

1+4s1+5sT0K4-K5 (3s)(1+3s)[T]-K6T-T-f2() II Ts = A(P)3 + B(P)2+ C(P)+ DTm = E(P)3 + F(P)2+ G(P)+ H

Ts = A(P)3 + B(P)2+ C(P)+ DTm = E(P)3 + F(P)2+ G(P)+ H

Table 3.3.4-1 (page 1 of 2) Remote Shutdown System 3.3.4 Remote Shutdown System Instrumentation and Controls

1. Reactivity Control FUNCTION/INSTRUMENT OR CONTROL PARAMETER

a. Source Range Neutron Flux b. Reactor Trip Breaker Position Indication

2. Reactor Coolant System (RCS) Pressure Control a. Pressurizer Pressure Indication or RCS Wide Range Pressure Indication

b. Pressurizer Power Operated Relief Valve (PORV) Control and Pressurizer Block Valve Control c. Pressurizer Heater Control 3. RCS Inventory Control a. Pressurizer Level Indication

b. Charging and Letdown Flow Control and Indication

4. Decay Heat Removal via Steam Generators (SGs) a. RCS Hot Leg Temperature Indication

b. AFW Controls

c. SG Pressure Indication and Control d. SG Level Indication and AFW Flow Indication

e. SG Tsat Indication

5. Decay Heat Removal via RHR System a. RHR Flow Control b. RHR Temperature Indication Watts Bar -Unit 2 3.3-50 REQUIRED NUMBER OF FUNCTIONS 1 per trip breaker 1 each per relief path 1 per loop (Refer to Note A on page 2 of 2) 1 per SG 1 per SG 1 per SG Amendment 19 Note A: Table 3.3.4-1 (page 2 of 2) Remote Shutdown System 3.3.4 Remote Shutdown System Instrumentation and Controls For Function 4a, the temperature indicator for RCS hot leg 3 is not required to be operable for the remainder of Cycle 2. If WBN Unit 2 enters Mode 3 or 4 prior to the Unit 2 Cycle 2 refueling outage, TVA will determine the cause of the inoperability of the temperature indicator for RCS hot leg 3 and the following actions will be taken: 1. If the problem is with the temperature modifier

circuit, the temperature modifier circuit will be repaired or replaced, and the temperature indicator for RCS hot leg 3 will be restored to OPERABLE status prior to plant startup.

2. If the problem is with the thermocouple, the thermocouple will be repaired or replaced, if WBN Unit 2 enters Mode 5 prior to the Unit 2 Cycle 2 refueling outage, and the temperature indicator for RCS hot leg 3 will be restored to OPERABLE status prior to plant startup.

Regardless of the above actions, the temperature indicator for RCS hot leg 3 will be restored to OPERABLE status no later than the end of the Unit 2 Cycle 2 refueling outage. Watts Bar -Unit 2 3.3-50a Amendment 19

3.3 INSTRUMENTATION CREVS Actuation Instrumentation 3.3.7 3.3.7 Control Room Emergency Ventilation System (CREVS) Actuation Instrumentation LCO 3.3.7 APPLICABILITY:

ACTIONS The CREVS actuation instrumentation for each Function in Table 3.3.7-1 shall be OPERABLE.

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

---

N 0 TE-------------------------------------------------------------

S e para te Condition entry is allowed for each Function.

CONDITION A. One or more Functions with A. 1 one channel or train inoperable.

Watts Bar -Unit 2 REQUIRED ACTION COMPLETION TIME Place one CREVS train in 7 days emergency radiation protection mode. (continued) 3.3-59 Amendment 9

SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS Loops -MODE 4 3.4.6 FREQUENCY SR 3.4.6.1 Verify two RCS loops are in operation when the rod 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> control system is capable of rod withdrawal.

SR 3.4.6.2 Verify one required RHR or RCS loop is in operation 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> when the rod control system is not capable of rod withdrawal.

SR 3.4.6.3 Verify SG secondary side water levels are greater 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> than or equal to 6% narrow range for required RCS loops. SR 3.4.6.4 Verify correct breaker alignment and indicated power 7 days are available to the required pump that is not in operation.

Watts Bar-Unit 2 3.4-11 Amendment 8

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 A. One EGTS train inoperable.

A.1 Restore EGTS train to OPERABLE status. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 5. SURVEILLANCE REQUIREMENTS SR 3.6.9.1 SR 3.6.9.2 Watts Bar -Unit 2 SURVEILLANCE Operate each EGTS train for 15 continuous minutes with heaters operating.

Perform required EGTS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). 3.6-22 EGTS 3.6.9 COMPLETION TIME 7 days 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours FREQUENCY 31 days In accordance with the VFTP (continued)

Amendment No. 15 I

SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.11.2 SR 3.6.11.3 SR 3.6.11.4 Watts Bar -Unit 2 SURVEILLANCE Verify total weight of stored ice is greater than or equal to 2,404,500 lb by: a. Weighing a representative sample of 2!: 144 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.

Verify azimuthal distribution of ice at a 95 percent confidence level by subdividing

weights, as determined by SR 3.6.11.2.a, into the following groups: 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. Verify, by visual inspection, accumulation of ice on structural members comprising flow channels through the ice bed is less than or equal to 15 percent blockage of the total flow area for each safety analysis section.

3.6-26 Ice Bed 3.6.11 FREQUENCY 18 months 18 months 18 months (continued)

Amendment 14

ACTIONS (continued)

CONDITION C. Required Action and C.1 associated Completion Time of Condition A or B AND not met in MODE 1, 2, 3, or 4. C.2 D. Required Action and D.1 associated Completion Time of Condition A not met in MODE 5 or 6, or during movement of irradiated fuel OR assemblies.

D.2 E. Two CREVS trains E.1 inoperable in MODE 1, 2, 3, or 4 due to actions taken as a result of a tornado warning.

F. Required Action and F.1 associated Completion Time of Condition E not met. F.2 Watts Bar -Unit 2 REQUIRED ACTION Be in MODE 3. Be in MODE 5. Place OPERABLE CREVS train in emergency mode. Suspend movement of irradiated fuel assemblies.

Restore one CREVS train to OPERABLE status. Be in MODE 3. AND Be in MODE 5. 3.7-22 CREVS 3.7.10 COMPLETION TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Immediately Immediately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 6 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)

Amendment 9

ACTIONS (continued)

CONDITION REQUIRED ACTION G. Two CREVS trains G.1 Suspend movement of inoperable in MODE 5 or 6, irradiated fuel assemblies or during movement of 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. inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B or E. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.10.1 Operate each CREVS train 15 minutes.

SR 3.7.10.2 Perform required CREVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). SR 3. 7.10.3 Verify each CREVS train actuates on an actual or simulated actuation signal. SR 3. 7.10.4 Perform required CRE unfiltered air inleakge testing in accordance with the Control Room Envelope Habitability Program.

Watts Bar -Unit 2 3.7-23 CREVS 3.7.10 COMPLETION TIME Immediately Immediately FREQUENCY 31 days In accordance with the VFTP 18 months In accordance with the Control Room Envelope Habitability Program Amendment 9

3. 7 PLANT SYSTEMS 3.7.12 Auxiliary Building Gas Treatment System (ABGTS) LCO 3.7.12 Two ABGTS trains shall be OPERABLE ABGTS 3.7.12 ------------------------------------

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

The Auxiliary Building Secondary Containment Enclosure (ABSCE) boundary may be opened intermittently under administrative controls that ensure the ABSCE can be closed consistent with the safety analysis.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ABGTS train A.1 Restore ABGTS train to 7 days inoperable OPERABLE status. B. Two ABGTS trains B.1 Initiate actions to Immediately inoperable due to implement mitigating inoperable ABSCE actions.

boundary.

AND B.2 Verify mitigating actions 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ensure main control room occupants do not exceed 10 CFR 50 Appendix A GDC 19 limits. AND B.3 Restore ABSCE 7 days boundary to OPERABLE status. (continued)

Watts Bar -Unit 2 3.7-26 Amendment 16 ACTIONS !continued)

CONDITION C. Required Action and associated Completion Time of Condition A or B not met. Two ABGTS trains inoperable for reasons other than Condition B. Watts Bar -Unit 2 C.1 AND C.2 REQUIRED ACTION Be in MODE 3. Be in MODE 5. 3.7-26a ABGTS 3.7.12 COMPLETION TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Amendment 16 I SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3. 7 .12.1 Operate each ABGTS train for 2'. 15 continuous minutes with the heaters operating.

SR 3.7.12.2 Perform required ABGTS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). SR 3.7.12.3 Verify each ABGTS train actuates on an actual or simulated actuation signal. SR 3. 7 .12.4 Verify one ABGTS train can maintain a pressure between -0.25 inches and -0.5 inches water gauge with respect to atmospheric pressure during the post accident mode of operation at a flow rate 2'. 9300 cfm and .s; 9900 cfm. Watts Bar -Unit 2 3.7-27 ABGTS 3.7.12 FREQUENCY 31 days In accordance with the VFTP 18 months 18 months on a STAGGERED TEST BASIS Amendment No. 15

ACTIONS CONDITION REQUIRED ACTION A. (continued)

A.3 Restore required offsite circuit to OPERABLE status. B. One DG inoperable.

8.1 Perform SR 3.8.1.1 for the required offsite circuits.

AND 8.2 Evaluate availability of 6.9 kV FLEX DG. AND 8.3 Declare required feature(s) supported by the inoperable DG inoperable when its required redundant feature(s) is inoperable.

AND Watts Bar -Unit 2 3.8-2 AC Sources Operating 3.8.1 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 13 days from discovery of failure to meet LCO 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoperability of redundant required features(s)

(continued)

Amendment 5

ACTIONS CONDITION B. (continued)

Watts Bar -Unit 2 B.4.1 OR B.4.2 AND B.5 REQUIRED ACTION Determine OPERABLE DGs are not inoperable due to common cause failure.

Perform SR 3.8.1.2 for OPERABLE DGs. Restore DG to OPERABLE status. 3.8-2a AC Sources -Operating 3.8.1 COMPLETION TIME I 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from discovery of unavailability of the 6.9 kV FLEX DG AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from discovery of Condition B entry ;:;:; 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> concurrent with unavailability of the 6.9 kV FLEX DG. AND 10 days AND 13 days from discovery of failure to meet LCO (continued)

Amendment 5

ACTIONS (continued)

CONDITION C. Two DGs in Train A inoperable.

Two DGs in Train B inoperable.

Watts Bar -Unit 2 REQUIRED ACTION C.1 Perform SR 3.8.1.1 for the required offsite circuits.

AND C.2 Declare required feature(s) supported by the inoperable DGs inoperable when its required redundant feature(s) is inoperable AND C.3.1 Determine OPERABLE DGs are not inoperable due to common cause failure.

OR C.3.2 Perform SR 3.8.1 .2 for OPERABLE DGs. AND 3.8-2b AC Sources -Operating 3.8.1 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours (continued)

Amendment 5

ACTIONS CONDITION REQUIRED ACTION C. (continued)

C.4 Restore DGs to OPERABLE status. D. Two required offsite circuits D. 1 Declare required inoperable.

feature(s) inoperable when its redundant required feature(s) is inoperable.

AND D.2 Restore one required offsite circuit to OPERABLE status. One required offsite circuit --------------------NOT'E-------------------

inoperable.

Enter applicable Conditions and AND Required Actions of LCO 3.8.9, "Distribution Systems-Operating,"

One or more DG(s) in 'Train when Condition E is entered with no AC power source to any train. A inoperable.

OR E.1 Restore required offsite One or more DG(s) in Train circuit to OPERABLE B inoperable.

status. OR E.2 Restore DG(s) to OPERABLE status. Watts Bar -Unit 2 3.8-3 AC Sources -Operating 3.8.1 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 6 days from discovery of failure to meet LCO 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from discovery of Condition D concurrent with inoperability of redundant required features 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 12 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)

Amendment 5

ACTIONS (continued)

CONDITION F. One or more DG(s) in Train A inoperable.

AND One or more DG(s) in Train B inoperable.

G. Required Action and Associated Completion Time of Condition A. B, C, D, E, or F not met. H. Two required offsite circuits inoperable.

AND One or more DG(s) in Train A inoperable.

OR One or more DG(s) in Train B inoperable.

I. One required offsite circuit inoperable.

AND One or more DG(s) in Train A inoperable.

AND One or more DG(s) in Train B inoperable.

Watts Bar -Unit 2 REQUIRED ACTION F.1 Restore DG(s) in Train A to OPERABLE status. OR F.2 Restore DG(s) in Train B to OPERABLE status. G.1 Be in MODE 3. AND G.2 Be in MODE 5. H.1 Enter LCO 3.0.3. 1.1 Enter LCO 3.0.3. 3.8-4 AC Sources -Operating 3.8.1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 2 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Immediately Immediately Amendment 5

Procedures,

Programs, and Manuals 5.7 5.7.2.12 Steam Generator (SG) Program (continued)

Watts Bar -Unit 2 2. Accident induced leakage performance criterion:

The secondary accident induced leakage rate for any design basis accident, other than an SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 1 gpm per SG. 3. The operational leakage performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE ... c. Provisions for SG tube plugging criteria.

Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

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

1. Tubes with service-induced flaws located in the portion of the tube from the top of the tubesheet to 1.64 inches below the top of the tubesheet, or from the bottom of the roll transition to 1.64 inches below the bottom of the roll transition, whichever is lower, shall be plugged.

Tubes with service-induced flaws located below this elevation do not require plugging.

5.0-16 Amendment No. 2 Procedures,

Programs, and Manuals 5.7 5.7.2.12 Steam Generator (SG) Program (continued)

Watts Bar -Unit 2 d. Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from 1.64 inches below the bottom of the roll transition or 1.64 inches below the top of the tubesheet, whichever is lower at the tube inlet, to 1.64 inches below the bottom of the roll transition or 1.64 inches below the top of the tubesheet, whichever is tower at the tube outlet, and that may satisfy the applicable tube plugging criteria.

In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection

methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

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

2. After the first refueling outage following SG installation, inspect each SG at least every 24 effective full power months or at least every refueling outage (whichever results in more frequent inspections).

In addition, inspect 100% of the tubes at sequential periods of 60 effective full power months beginning after the first refueling outage inspection following SG installation.

Each 60 effective full power month inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated.

5.0-17 Amendment No. 2 Procedures

Programs, and Manuals 5.7 5.7.2.12 Steam Generator (SG) Program (continued)

Watts Bar -Unit 2 The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. 3. If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive

testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s),

then the indication need not be treated as a crack. e. Provisions for monitoring operational primary-to-secondary LEAKAGE.

5.0-17a Amendment No. 2

Procedures,

Programs, and Manuals 5.7 5.7 Procedures,

Programs, and Manuals 5. 7 .2.18 Safety Function Determination Program (SFDP) (continued)

A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed.

For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and: a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists.

If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

5. 7 .2.19 Containment Leakage Rate Testing Program Watts Bar -Unit 2 A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50 Appendix J, Option B, as modified by approved exemptions.

This program shall be in accordance with the guidelines contained in Regulatory Guide (RG) 1.163, "Performance-Based Containment Leak-Test Program,"

dated September 1995, with the exception that for the containment isolation valves listed in Table 5. 7.2-1, an extension of their Type C local leak rate test is permitted on a time basis and expires prior to WBN Unit 2 entering Mode 4, following the Cycle 1 refueling outage, but no later than December 31, 2017. For containment leakage rate testing purposes, a value of 15.0 psig, which is equivalent to the maximum allowable internal containment

pressure, is utilized for Pa to bound the peak calculated containment internal pressure for the design basis loss of coolant accident.

The maximum allowable containment leakage rate, La, at Pa, is 0.25% of the primary containment air weight per day. (continued) 5.0-25 Amendment 11 Containment Penetration X-29 X-44 X-47A X-47B X-56A X-57A X-58A X-59A X-60A X-61A X-62A X-63A Watts Bar -Unit 2 Procedures,

Programs, and Manuals 5.7 Table-5.

7 .2-1 Description Valve number RCP oil cooler CCS Return Outboard FCV-70-92 RCP Seal Water Return Outboard FCV-62-63 Glycol Supply Inboard FCV-61-192 CKV-61-533 Glycol Supply Outboard FCV-61-191 Glycol Return Inboard FCV-61-194 CKV-61-680 Glycol Return Outboard FCV-61-193 Lower Containment ERCW Supply I FCV-67-113 CKV-67-10540 Lower Containment ERCW Suooly FCV-67-107 FCV-67-111 Lower Containment ERCW Return CKV-67-5750 FCV-67-112 FCV-67-89 Lower Containment ERCW Supply CKV-67-1054A FCV-67-83 FCV-67-87 Lower Containment ERCW Return CKV-67-575A FCV-67-88 FCV-67-105 Lower Containment ERCW Supply CKV-67-10548 FCV-67-99 FCV-67-103 Lower Containment ERCW Return CKV-67-5758 FCV-67-104 FCV-67-97 Lower Containment ERCW Supply CKV-67-1054C FCV-67-91 FCV-67-95 Lower Containment ERCW Return CKV-67-575C FCV-67-96 (continued) 5.0-25a Amendment 11 I I I I

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 TENNESSEE VALLEY AUTHORITY DOCKET NO. 50-391 WATTS BAR NUCLEAR PLANT, UNIT 2 FACILITY OPERATING LICENSE License No. NPF-96 1. The Nuclear Regulatory Commission (the Commission or the NRC) has found that: A. The application for an operating license filed by the Tennessee Valley Authority (TVA, the licensee) complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I, and all required notifications to other agencies or bodies have been duly made; B. Construction of the Watts Bar Nuclear Plant, Unit 2 (the facility) has been substantially completed in conformity with Construction Permit No. CPPR-92 and the application, as amended, the provisions of the Act and the rules and regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission; D. There is reasonable assurance (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 1 O CFR Chapter I; E. TVA is technically qualified to engage in the activities authorized by this license in accordance with the Commission's regulations set forth in 1 O CFR Chapter I; F. TVA has satisfied the applicable provisions of 1 O CFR Part 140, "Financial Protection Requirements and Indemnity Agreements;"

G. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental,

economic, technical and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Facility Operating License No. NPF-96, subject to the conditions for protection of the environment set forth in the Environmental Protection Plan attached as Appendix B, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and I. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 1 O CFR Parts 30, 40, and 70. 2. Based on the foregoing findings regarding this facility, Facility Operating License No. NPF-96 is hereby issued to TVA to read as follows:

A. This license applies to the Watts Bar Nuclear Plant, Unit 2, a pressurized water reactor and associated equipment (the facility) owned by TV A. The facility is located on the west bank of the Chickamauga Lake on TVA's site in Rhea County, Tennessee, and is described in TVA's Final Safety Analysis Report, as supplemented and amended up to Amendment No. 114 and in the Final Environmental Statement, Watts Bar Nuclear Plant Units 1 and 2, as supplemented and amended; B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses TVA: (1) Pursuant to Section 103 of the Act and 1 O CFR Part 50, to possess, use, and operate the facility at the designated location in Rhea County, Tennessee, in accordance with the procedures and limitations set forth in this license; (2) Pursuant to the Act and 1 O CFR Part 70, to receive,

possess, and use at any time, special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, and as. described in the Final Safety Analysis Report, as supplemented and amended; (3) Pursuant to the Act and 1 O CFR Parts 30, 40 and 70, to receive,

possess, and use at any time, any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) 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) Pursuant to the Act and 1 O CFR Parts 30 and 70, to possess but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

Unit 2 C. The license shall be deemed to contain and is subject to the conditions specified in the Commission's 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. 19 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 for Cycles 1 and 2 only. PAD4TCD may not be used to establish core operating limits for subsequent reload cycles. (5) By December 31, 2017, 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:

Facility License No. NPF-96 Amendment No. 19 TVA may make changes to the approved fire protection program without prior approval of the Commission, only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire. (9) By May 31, 2018, TVA shall report that a listing organization acceptable to the NRG (as the Authority Having Jurisdiction) has determined that the fire detection monitoring panel in the main control room either meets the appropriate designated standards or has been tested and found suitable for the specified purpose.

(10) TVA will verify for each core reload that the actions taken if Faw(Z) is not within limits will assure that the limits on core power peaking Fa(Z) remain below the initial total peaking factor assumed in the accident analyses.

(11) TVA will implement the compensatory measures described in Section 3.4, "Additional Compensatory Measures,"

of TV A letter CNL-18-012, dated January 17, 2018, during the timeframe the temperature indicator for RCS hot leg 3 is not required to be operable for the remainder of Cycle 2. If the RCS hot leg 3 temperature indicator is returned to operable status prior to the end of Cycle 2, then these compensatory measures are no longer required.

D. The licensee shall have and maintain financial protection of such types and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims. F. This license is effective as of the date of issuance and shall expire at midnight on October 21, 2055. Appendices:

1. Appendix A -FOR THE NUCLEAR REGULATORY COMMISSION original signed by William M. Dean, Director Office of Nuclear Reactor Regulation Technical Specifications

2. Appendix B -Environmental Protection Plan Date of Issuance:

October 22, 2015 Amendment No. 19

(F)

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCO 3.0.2 LCO 3.0.3 LCO 3.0.4 Watts Bar -Unit 2 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2, 3.0.7, and 3.0.8. Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6. If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s),

completion of the Required Action(s) is not required unless otherwise stated. When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable.

Action shall be initiated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, in: a. MODE 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />; b. MODE 4 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />; and c. MODE 5 within 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br />. Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4. When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made: a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; (continued) 3.0-1 Amendment 6

LCO Applicability 3.0 3.0 APPLICABILITY (continued)

LCO 3.0.7 LCO 3.0.8 Watts Bar-Unit 2 Test Exception LCO 3.1.9 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations.

Unless otherwise specified, all other TS requirements remain unchanged.

Compliance with Test Exception LCOs is optional.

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

When one or more required snubbers are unable to perform their associated support function(s),

any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; or b. the snubbers not able to perform their associated support function{s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. At the end of the specified period, the required snubbers must be able to perform their associated support function(s),

or the affected supported system LCO(s) shall be declared not met. 3.0-3 Amendment 6 I SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SR 3.0.2 SR 3.0.3 Watts Bar -Unit 2 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits. The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met. In addition, for each of the SRs listed in Table SR 3.0.2-1 the specified Frequency is met if the Surveillance is performed on or before the date listed on Table SR 3.0.2-1.

This extension of the test intervals for these SRs is permitted on a one-time basis to be completed no later than November 30, 2017. For Frequencies specified as "once," the above interval extension does not apply. If a Completion Time requires periodic performance on a "once per ... " basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or up to the limit of the specified Frequency, whichever is greater.

This delay period is permitted to allow performance of the Surveillance.

A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

3.0-4 (continued)

Amendment 3, 12 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.3 (continued)

SR 3.0.4 Watts Bar -Unit 2 When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4. This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. 3.0-5 Amendment No. 3 I SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Table SR 3.0.2-1 Frequency Surveillance Requirement (SR) Description of SR Requirement Extension Limit Perform TADOT of the Safety Injection (SI) Input from 10/31/17 3.3.1.13, Table3.3.1-1, Function 15 Engineered Safety Feature Actuation System to Reactor Trip Function 3.3.2.5, Table 3.3.2-1, Function 1.b Perform SLAVE RELAY TEST of the Safety Injection Automatic Actuation Logic and Actuation Relays Function 10/31/17 3.3.2.5, Table 3.3.2-1, Function

2. rm SLAVE RELAY TEST of the Containment Spray 10/31/17 matic Actuation Logic and Actuation Relays Function rm SLAVE RELAY TEST of the Containment Isolation 10/31/17 3.3.2.5, Table 3.3.2-1, Function 3.a(2) Phase A Isolation Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Containment Isolation 10/31/17 3.3.2.5, Table 3.3.2-1, Function 3.b(2} Phase B Isolation Automatic Actuation Logic and Actuation Relavs Function 3.3.2.5, Table 3.3.2-1, Function 4.b Perform SLAVE RELAY TEST of the Steam Line Isolation 10/31/17 Automatic Actuation Loaic and Actuation Relays Function Perform SLAVE RELAY TEST of the Turbine Trip and 10/31/17 3.3.2.5, Table 3.3.2-1, Function 5.a Feedwater Isolation Automatic Actuation Logic and Actuation Relays Function

.

RELAY TEST of the Auxiliary Feedwater 3.3.2.5, Table 3.3.2-1, Function 6*a atic Actuation Loaic and Actuation Relays Function 10/31/17 3.3.2.5, Table 3.3.2-1, Function 7.a 3.3.2.7, Table 3.3.2-1, Function 1.b 3.3.2.7, Table 3.3.2-1, Function 3.a(2) 3.3.2.7, Table 3.3.2-1, Function 3.b(2) 3.3.2.8, Table 3.3.2-1, Function 1.a 3.3.2.8, Table 3.3.2-1, Function 2.a 3.3.2.8, Table 3.3.2-1, Function 3.a(1) 3.3.2.8, Table 3.3.2-1, Function 3.b(1) 3.3.2.10, Table 3.3.2-1, Function 1.c 3.3.2.10, Table 3.3.2-1, Function 1.d 3.3.2.10, Table 3.3.2-1, Function 1.e 3.3.2.10, Table 3.3.2-1, Function 2.c 3.3.2.10, Table 3.3.2-1, Function 3.b(3} Watts Bar Unit 2 Perform SLAVE RELAY TEST of the Automatic Switchover 10/31/17 to Containment Sump Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Safety Injection 10/31/17 Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Containment Isolation 10/31/17 Phase A Isolation Automatic Actuation Logic and Actuation Relays Function Perform SLAVE RELAY TEST of the Containment Isolation 10/31 /17 Phase B Isolation Automatic Actuation Logic and Actuation Relavs Function Perform TADOT of the Safety Injection Manual Initiation 10/31/17 Function Perform TADOT of the Containment Spray Manual 10/31/17 Initiation Function Perform TADOT of the Containment Isolation Phase A Isolation Manual Initiation Function 10/31/17 Perform TADOT of the Containment Isolation Phase B 10/31/17 Isolation Manual Initiation Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Safety Injection Containment Pressure

-High Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Safety Injection Pressurizer Pressure

-Low Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Safety Injection Steam Line Pressure

-Low Function Verify ESFAS RESPONSE TIMES are within limit for the 10/31/17 Containment Pressure

-High High Function Verify ESFAS RESPONSE TIMES are within limit for the Containment Isolation Phase B Isolation Containment 10/31/17 Pressure

-High High Function 3.0-6 (continued)

Amendment No. 3, 10, 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.3.2.10, Table 3.3.2-1, Function 6.b 3.3.2.10, Table 3.3.2-1, Function 6.e 3.3.2.10, Table 3.3.2-1, Function 7.b 3.3.3.2, Table 3.3.3-1, Function 5 3.3.3.2, Table 3.3.3-1, Function 6 3.:3.3.3, Table 3.3.3-1, Function 11 3.3.4.2, Table 3.3.4-1, Function 2.b 3.3.4.2, Table 3.3.4-1, Function 2.c 3.:3.4.2, Table 3.3.4-1, Function 3.b Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify ESFAS RESPONSE TIMES are within limit for the Auxiliary Feedwater SG Water Level -Low Low Coincident with: 1) Vessel !J. T Equivalent to power:;;;

50% RTP With a time delay (Ts) if one SG is affected or A time 10/31 /17 delay (Tm) if two or more SGs are affected OR 2) Vessel !J.T equivalent to power> 50% RTP with no time delay (Ts and Tm = 0) Function Verify ESFAS RESPONSE TIMES are within limit for the Auxiliary Feedwater Trip of all Turbine Driven Main 10/31/17 Feedwater Pumps Function Verify ESFAS RESPONSE TIMES are within limit for the Automatic Switchover to Containment Sump Refueling Water Storage Tank (RWST) Level Low Coincident with 10/31/17 Safety Injection and Coincident with Containment Sump Level -High Function Perform CHANNEL CALIBRATION of the RCS Pressur 1/17 (Wide Range) Function Perform CHANNEL CALIBRATION of the Reactor Vessel 10/31/17 Water Level Function Perform TADOT of the Containment Isolation Valve 10/31/17 Position Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Reactor Coolant System (RCS) Pressure Control Pressurizer 10/31/17 Power Operated Relief Valve (PORV) Control and Pressurizer Block Valve Control Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Reactor 10/31/17 Coolant System (RCS) Pressure Control Pressurizer Heater Control Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Reactor 10/31/17 Coolant System (RCS) Pressure Control Pressurizer Heater Control Function 3.0-7 (continued)

Amendment No. 10, 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.3.4.2, Table 3.3.4-1, Function 4.b 3.3.4.2, Table 3.3.4-1, Function 4.c 3.3.4.2, Table 3.3.4-1, Function 5.a 3.3.4.3, Table 3.3.4-1, Function 2.b 3.3.4.3, Table 3.3.4-1, Function 2.c 3.3.4.3, Table 3.3.4-1, Function 4.c 3.3.4.3, Table 3.3.4-1, Function 4.e 3.3.6.5, Table 3.3.6-1, Function 2 3.3.6.6, Table 3.3.6-1, Function 1 3.4.12.8 3.5.2.5 3.5.2.6 3.6.3.6 3.6.6.3 Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify each required control circuit and transfer switch is capable of performing the intended function for the Decay 10131117 Heat Removal via Steam Generators (SGs) AFW Controls Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Decay 10/31/17 Heat Removal via Steam Generators (SGs) SG Pressure Indication and Control Function Verify each required control circuit and transfer switch is capable of performing the intended function for the Decay 10/31/17 Heat Removal via RHR System RHR Flow Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Reactor Coolant System (RCS) Pressure Control Pressurizer Power Operated Relief 10131/17 Valve (PORV) Control and Pressurizer Block Valve Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Reactor Coolant System 10131/17 (RCS) Pressure Control Pressurizer Heater Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Decay Heat Removal via 10/31/17 Steam Generators (SGs) SG Pressure Indication and Control Function Perform CHANNEL CALIBRATION for each required instrumentation channel for the Decay Heat Removal via 10/31117 Steam Generators (SGs) SG Tsat Indication Function Perform SLAVE RELAY TEST of the Containment Vent 10/31/17 Isolation Instrumentation Automatic Actuation Logic and Actuation Relays Function Perform TADOT of the Containment Vent Isolation 10/31/17 Instrumentation Manual Initiation Function Perform CHANNEL CALIBRATION for each required 10/31/17 PORV actuation channel Verify each ECCS automatic valve in the flow path that is 10/31/17 not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each ECCS pump starts automatically on an actual 10/31 /17 or simulated actuation signal. Verify each automatic containment isolation valve that is 10/31/17 not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal Verify each automatic containment spray valve in the flow 10/31/17 path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation sianal 3.0-8 (continued)

Amendment No. 12, 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.6.6.4 3.6.9.3 3.6.11.2 3.6.11.3 3.6.13.5 3.7.7.3 3.7.7.4 3.7.8.2 3.7.8.3 Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify each containment spray pump starts automatically 10/31/17 on an actual or simulated actuation signal Verify each Emergency Gas Treatment System (EGTS) train actuates on an actual or simulated actuation signal 10/31/17 Verify total weight of stored ice is greater than or equal to 2,404,500 lb by: a. Weighing a representative sample of 144 ice baskets and verifying each basket contains greater than or equal 10/31/17 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.

Verify azimuthal distribution of ice at a 95 percent confidence level by subdividing

weights, as determined by SR 3.6.11.2.a, into the following groups: a. Group 1-bays 1 through 8; b. Group 2-bays 9 through 16; and 10/31 /17 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. Visually 95% of the divider barrier seal length, 10/31/17 and verify: a. Seal and seal mounting bolts are properly installed; and b. Seal material shows no evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical aooearance Verify each Component Cooling System (CCS) automatic 10/31/17 valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation sional Verify each CCS pump starts automatically on an actual or 10/31/17 simulated actuation sianal Verify each Essential Raw Cooling Water (ERCW) 10/31/17 automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation sianal Verify each ERCW pump starts automatically on an actual 10/31/17 or simulated actuation signal 3.0-9 (continued)

Amendment 12, 13, 14 3.0 SR APPLICABILITY Surveillance Requirement (SR) 3.8.1.9 3.8.110 3.8. 1. 11 3.8.1.12 3.8.1.13 Watts Bar -Unit 2 SR Applicability 3.0 Table SR 3.0.2-1 Frequency

. Description of SR Requirement Extension Limit Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is s 66.75 Hz; b. Within 3 seconds following load rejection, the voltage is 11/30/17 6555 V and s 7260 V; and c. Within 4 seconds following load rejection, the frequency 59.8 Hz and s 60.1 Hz. Verify each DG operating at a power 0.8 ands 0.9 does not trip and voltage is maintained s 8880 V during 11/30/17 and following a load rejection 3960 kW and s 4400 kW and 2970 kVAR ands 3300 kVAR Verify on an actual or simulated loss of offsite power signal: 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 s 10 seconds,

2. energizes auto-connected shutdown loads through 11/30/17 automatic load sequencer,

3. maintains steady state voltage 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 5 minutes Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each Unit 2 DG auto-starts from standby condition and: 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 11/30/17 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. Verify each DG's automatic trips are bypassed on automatic or emergency start signal except: 11/30/17

a. Engine overspeed; and b. Generator differential current 3.0-10 (continued)

Amendment No. 13 SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

Surveillance Requirement (SR) 3.81.16 3.8.1.17 3.8.1.18 3.8.1.19 5.7.2.4b Watts Bar -Unit 2 Table SR 3.0.2-1 Frequency Description of SR Requirement Extension Limit Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite 11 /30/17 power; b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation Verify, DG 2A-A and 2B-B operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and 11/30/17

b. Automatically energizing the emergency load from offsite power. Verify the time delay setting for each sequenced load block is within limits for each accident condition and non-accident 11/30/17 condition load sequence.

Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: 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 s1 O seconds, 11/30/17

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

3. achieves steady state voltage:

?>: 6800 V and s 7260 V, 4. achieves steady state frequency

?>: 59.8 Hz and s 60.1 Hz, and 5. supplies permanently connected and auto-connected emergency loads for?>: 5 minutes.

Perform integrated leak test for each system at least once per 18 months. Specifically, only the centrifugal charging 10/31 /17 pump injection portion of the safety injection system 3.0-11 (continued)

Amendment No. 13

FFF FF F

F

1+4s1+5sT0K4-K5 (3s)(1+3s)[T]-K6T-T-f2() II Ts = A(P)3 + B(P)2+ C(P)+ DTm = E(P)3 + F(P)2+ G(P)+ H

Ts = A(P)3 + B(P)2+ C(P)+ DTm = E(P)3 + F(P)2+ G(P)+ H

Table 3.3.4-1 (page 1 of 2) Remote Shutdown System 3.3.4 Remote Shutdown System Instrumentation and Controls

1. Reactivity Control FUNCTION/INSTRUMENT OR CONTROL PARAMETER

a. Source Range Neutron Flux b. Reactor Trip Breaker Position Indication

2. Reactor Coolant System (RCS) Pressure Control a. Pressurizer Pressure Indication or RCS Wide Range Pressure Indication

b. Pressurizer Power Operated Relief Valve (PORV) Control and Pressurizer Block Valve Control c. Pressurizer Heater Control 3. RCS Inventory Control a. Pressurizer Level Indication

b. Charging and Letdown Flow Control and Indication

4. Decay Heat Removal via Steam Generators (SGs) a. RCS Hot Leg Temperature Indication

b. AFW Controls

c. SG Pressure Indication and Control d. SG Level Indication and AFW Flow Indication

e. SG Tsat Indication

5. Decay Heat Removal via RHR System a. RHR Flow Control b. RHR Temperature Indication Watts Bar -Unit 2 3.3-50 REQUIRED NUMBER OF FUNCTIONS 1 per trip breaker 1 each per relief path 1 per loop (Refer to Note A on page 2 of 2) 1 per SG 1 per SG 1 per SG Amendment 19 Note A: Table 3.3.4-1 (page 2 of 2) Remote Shutdown System 3.3.4 Remote Shutdown System Instrumentation and Controls For Function 4a, the temperature indicator for RCS hot leg 3 is not required to be operable for the remainder of Cycle 2. If WBN Unit 2 enters Mode 3 or 4 prior to the Unit 2 Cycle 2 refueling outage, TVA will determine the cause of the inoperability of the temperature indicator for RCS hot leg 3 and the following actions will be taken: 1. If the problem is with the temperature modifier

circuit, the temperature modifier circuit will be repaired or replaced, and the temperature indicator for RCS hot leg 3 will be restored to OPERABLE status prior to plant startup.

2. If the problem is with the thermocouple, the thermocouple will be repaired or replaced, if WBN Unit 2 enters Mode 5 prior to the Unit 2 Cycle 2 refueling outage, and the temperature indicator for RCS hot leg 3 will be restored to OPERABLE status prior to plant startup.

Regardless of the above actions, the temperature indicator for RCS hot leg 3 will be restored to OPERABLE status no later than the end of the Unit 2 Cycle 2 refueling outage. Watts Bar -Unit 2 3.3-50a Amendment 19

3.3 INSTRUMENTATION CREVS Actuation Instrumentation 3.3.7 3.3.7 Control Room Emergency Ventilation System (CREVS) Actuation Instrumentation LCO 3.3.7 APPLICABILITY:

ACTIONS The CREVS actuation instrumentation for each Function in Table 3.3.7-1 shall be OPERABLE.

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

---

N 0 TE-------------------------------------------------------------

S e para te Condition entry is allowed for each Function.

CONDITION A. One or more Functions with A. 1 one channel or train inoperable.

Watts Bar -Unit 2 REQUIRED ACTION COMPLETION TIME Place one CREVS train in 7 days emergency radiation protection mode. (continued) 3.3-59 Amendment 9

SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS Loops -MODE 4 3.4.6 FREQUENCY SR 3.4.6.1 Verify two RCS loops are in operation when the rod 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> control system is capable of rod withdrawal.

SR 3.4.6.2 Verify one required RHR or RCS loop is in operation 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> when the rod control system is not capable of rod withdrawal.

SR 3.4.6.3 Verify SG secondary side water levels are greater 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> than or equal to 6% narrow range for required RCS loops. SR 3.4.6.4 Verify correct breaker alignment and indicated power 7 days are available to the required pump that is not in operation.

Watts Bar-Unit 2 3.4-11 Amendment 8

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 A. One EGTS train inoperable.

A.1 Restore EGTS train to OPERABLE status. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 5. SURVEILLANCE REQUIREMENTS SR 3.6.9.1 SR 3.6.9.2 Watts Bar -Unit 2 SURVEILLANCE Operate each EGTS train for 15 continuous minutes with heaters operating.

Perform required EGTS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). 3.6-22 EGTS 3.6.9 COMPLETION TIME 7 days 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours FREQUENCY 31 days In accordance with the VFTP (continued)

Amendment No. 15 I

SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.11.2 SR 3.6.11.3 SR 3.6.11.4 Watts Bar -Unit 2 SURVEILLANCE Verify total weight of stored ice is greater than or equal to 2,404,500 lb by: a. Weighing a representative sample of 2!: 144 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.

Verify azimuthal distribution of ice at a 95 percent confidence level by subdividing

weights, as determined by SR 3.6.11.2.a, into the following groups: 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. Verify, by visual inspection, accumulation of ice on structural members comprising flow channels through the ice bed is less than or equal to 15 percent blockage of the total flow area for each safety analysis section.

3.6-26 Ice Bed 3.6.11 FREQUENCY 18 months 18 months 18 months (continued)

Amendment 14

ACTIONS (continued)

CONDITION C. Required Action and C.1 associated Completion Time of Condition A or B AND not met in MODE 1, 2, 3, or 4. C.2 D. Required Action and D.1 associated Completion Time of Condition A not met in MODE 5 or 6, or during movement of irradiated fuel OR assemblies.

D.2 E. Two CREVS trains E.1 inoperable in MODE 1, 2, 3, or 4 due to actions taken as a result of a tornado warning.

F. Required Action and F.1 associated Completion Time of Condition E not met. F.2 Watts Bar -Unit 2 REQUIRED ACTION Be in MODE 3. Be in MODE 5. Place OPERABLE CREVS train in emergency mode. Suspend movement of irradiated fuel assemblies.

Restore one CREVS train to OPERABLE status. Be in MODE 3. AND Be in MODE 5. 3.7-22 CREVS 3.7.10 COMPLETION TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Immediately Immediately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 6 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)

Amendment 9

ACTIONS (continued)

CONDITION REQUIRED ACTION G. Two CREVS trains G.1 Suspend movement of inoperable in MODE 5 or 6, irradiated fuel assemblies or during movement of 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. inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B or E. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.10.1 Operate each CREVS train 15 minutes.

SR 3.7.10.2 Perform required CREVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). SR 3. 7.10.3 Verify each CREVS train actuates on an actual or simulated actuation signal. SR 3. 7.10.4 Perform required CRE unfiltered air inleakge testing in accordance with the Control Room Envelope Habitability Program.

Watts Bar -Unit 2 3.7-23 CREVS 3.7.10 COMPLETION TIME Immediately Immediately FREQUENCY 31 days In accordance with the VFTP 18 months In accordance with the Control Room Envelope Habitability Program Amendment 9

3. 7 PLANT SYSTEMS 3.7.12 Auxiliary Building Gas Treatment System (ABGTS) LCO 3.7.12 Two ABGTS trains shall be OPERABLE ABGTS 3.7.12 ------------------------------------

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

The Auxiliary Building Secondary Containment Enclosure (ABSCE) boundary may be opened intermittently under administrative controls that ensure the ABSCE can be closed consistent with the safety analysis.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ABGTS train A.1 Restore ABGTS train to 7 days inoperable OPERABLE status. B. Two ABGTS trains B.1 Initiate actions to Immediately inoperable due to implement mitigating inoperable ABSCE actions.

boundary.

AND B.2 Verify mitigating actions 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ensure main control room occupants do not exceed 10 CFR 50 Appendix A GDC 19 limits. AND B.3 Restore ABSCE 7 days boundary to OPERABLE status. (continued)

Watts Bar -Unit 2 3.7-26 Amendment 16 ACTIONS !continued)

CONDITION C. Required Action and associated Completion Time of Condition A or B not met. Two ABGTS trains inoperable for reasons other than Condition B. Watts Bar -Unit 2 C.1 AND C.2 REQUIRED ACTION Be in MODE 3. Be in MODE 5. 3.7-26a ABGTS 3.7.12 COMPLETION TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Amendment 16 I SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3. 7 .12.1 Operate each ABGTS train for 2'. 15 continuous minutes with the heaters operating.

SR 3.7.12.2 Perform required ABGTS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). SR 3.7.12.3 Verify each ABGTS train actuates on an actual or simulated actuation signal. SR 3. 7 .12.4 Verify one ABGTS train can maintain a pressure between -0.25 inches and -0.5 inches water gauge with respect to atmospheric pressure during the post accident mode of operation at a flow rate 2'. 9300 cfm and .s; 9900 cfm. Watts Bar -Unit 2 3.7-27 ABGTS 3.7.12 FREQUENCY 31 days In accordance with the VFTP 18 months 18 months on a STAGGERED TEST BASIS Amendment No. 15

ACTIONS CONDITION REQUIRED ACTION A. (continued)

A.3 Restore required offsite circuit to OPERABLE status. B. One DG inoperable.

8.1 Perform SR 3.8.1.1 for the required offsite circuits.

AND 8.2 Evaluate availability of 6.9 kV FLEX DG. AND 8.3 Declare required feature(s) supported by the inoperable DG inoperable when its required redundant feature(s) is inoperable.

AND Watts Bar -Unit 2 3.8-2 AC Sources Operating 3.8.1 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 13 days from discovery of failure to meet LCO 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoperability of redundant required features(s)

(continued)

Amendment 5

ACTIONS CONDITION B. (continued)

Watts Bar -Unit 2 B.4.1 OR B.4.2 AND B.5 REQUIRED ACTION Determine OPERABLE DGs are not inoperable due to common cause failure.

Perform SR 3.8.1.2 for OPERABLE DGs. Restore DG to OPERABLE status. 3.8-2a AC Sources -Operating 3.8.1 COMPLETION TIME I 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from discovery of unavailability of the 6.9 kV FLEX DG AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from discovery of Condition B entry ;:;:; 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> concurrent with unavailability of the 6.9 kV FLEX DG. AND 10 days AND 13 days from discovery of failure to meet LCO (continued)

Amendment 5

ACTIONS (continued)

CONDITION C. Two DGs in Train A inoperable.

Two DGs in Train B inoperable.

Watts Bar -Unit 2 REQUIRED ACTION C.1 Perform SR 3.8.1.1 for the required offsite circuits.

AND C.2 Declare required feature(s) supported by the inoperable DGs inoperable when its required redundant feature(s) is inoperable AND C.3.1 Determine OPERABLE DGs are not inoperable due to common cause failure.

OR C.3.2 Perform SR 3.8.1 .2 for OPERABLE DGs. AND 3.8-2b AC Sources -Operating 3.8.1 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours (continued)

Amendment 5

ACTIONS CONDITION REQUIRED ACTION C. (continued)

C.4 Restore DGs to OPERABLE status. D. Two required offsite circuits D. 1 Declare required inoperable.

feature(s) inoperable when its redundant required feature(s) is inoperable.

AND D.2 Restore one required offsite circuit to OPERABLE status. One required offsite circuit --------------------NOT'E-------------------

inoperable.

Enter applicable Conditions and AND Required Actions of LCO 3.8.9, "Distribution Systems-Operating,"

One or more DG(s) in 'Train when Condition E is entered with no AC power source to any train. A inoperable.

OR E.1 Restore required offsite One or more DG(s) in Train circuit to OPERABLE B inoperable.

status. OR E.2 Restore DG(s) to OPERABLE status. Watts Bar -Unit 2 3.8-3 AC Sources -Operating 3.8.1 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 6 days from discovery of failure to meet LCO 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from discovery of Condition D concurrent with inoperability of redundant required features 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 12 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)

Amendment 5

ACTIONS (continued)

CONDITION F. One or more DG(s) in Train A inoperable.

AND One or more DG(s) in Train B inoperable.

G. Required Action and Associated Completion Time of Condition A. B, C, D, E, or F not met. H. Two required offsite circuits inoperable.

AND One or more DG(s) in Train A inoperable.

OR One or more DG(s) in Train B inoperable.

I. One required offsite circuit inoperable.

AND One or more DG(s) in Train A inoperable.

AND One or more DG(s) in Train B inoperable.

Watts Bar -Unit 2 REQUIRED ACTION F.1 Restore DG(s) in Train A to OPERABLE status. OR F.2 Restore DG(s) in Train B to OPERABLE status. G.1 Be in MODE 3. AND G.2 Be in MODE 5. H.1 Enter LCO 3.0.3. 1.1 Enter LCO 3.0.3. 3.8-4 AC Sources -Operating 3.8.1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 2 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Immediately Immediately Amendment 5

Procedures,

Programs, and Manuals 5.7 5.7.2.12 Steam Generator (SG) Program (continued)

Watts Bar -Unit 2 2. Accident induced leakage performance criterion:

The secondary accident induced leakage rate for any design basis accident, other than an SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 1 gpm per SG. 3. The operational leakage performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE ... c. Provisions for SG tube plugging criteria.

Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

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

1. Tubes with service-induced flaws located in the portion of the tube from the top of the tubesheet to 1.64 inches below the top of the tubesheet, or from the bottom of the roll transition to 1.64 inches below the bottom of the roll transition, whichever is lower, shall be plugged.

Tubes with service-induced flaws located below this elevation do not require plugging.

5.0-16 Amendment No. 2 Procedures,

Programs, and Manuals 5.7 5.7.2.12 Steam Generator (SG) Program (continued)

Watts Bar -Unit 2 d. Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from 1.64 inches below the bottom of the roll transition or 1.64 inches below the top of the tubesheet, whichever is lower at the tube inlet, to 1.64 inches below the bottom of the roll transition or 1.64 inches below the top of the tubesheet, whichever is tower at the tube outlet, and that may satisfy the applicable tube plugging criteria.

In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection

methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

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

2. After the first refueling outage following SG installation, inspect each SG at least every 24 effective full power months or at least every refueling outage (whichever results in more frequent inspections).

In addition, inspect 100% of the tubes at sequential periods of 60 effective full power months beginning after the first refueling outage inspection following SG installation.

Each 60 effective full power month inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated.

5.0-17 Amendment No. 2 Procedures

Programs, and Manuals 5.7 5.7.2.12 Steam Generator (SG) Program (continued)

Watts Bar -Unit 2 The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. 3. If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive

testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s),

then the indication need not be treated as a crack. e. Provisions for monitoring operational primary-to-secondary LEAKAGE.

5.0-17a Amendment No. 2

Procedures,

Programs, and Manuals 5.7 5.7 Procedures,

Programs, and Manuals 5. 7 .2.18 Safety Function Determination Program (SFDP) (continued)

A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed.

For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and: a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists.

If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

5. 7 .2.19 Containment Leakage Rate Testing Program Watts Bar -Unit 2 A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50 Appendix J, Option B, as modified by approved exemptions.

This program shall be in accordance with the guidelines contained in Regulatory Guide (RG) 1.163, "Performance-Based Containment Leak-Test Program,"

dated September 1995, with the exception that for the containment isolation valves listed in Table 5. 7.2-1, an extension of their Type C local leak rate test is permitted on a time basis and expires prior to WBN Unit 2 entering Mode 4, following the Cycle 1 refueling outage, but no later than December 31, 2017. For containment leakage rate testing purposes, a value of 15.0 psig, which is equivalent to the maximum allowable internal containment

pressure, is utilized for Pa to bound the peak calculated containment internal pressure for the design basis loss of coolant accident.

The maximum allowable containment leakage rate, La, at Pa, is 0.25% of the primary containment air weight per day. (continued) 5.0-25 Amendment 11 Containment Penetration X-29 X-44 X-47A X-47B X-56A X-57A X-58A X-59A X-60A X-61A X-62A X-63A Watts Bar -Unit 2 Procedures,

Programs, and Manuals 5.7 Table-5.

7 .2-1 Description Valve number RCP oil cooler CCS Return Outboard FCV-70-92 RCP Seal Water Return Outboard FCV-62-63 Glycol Supply Inboard FCV-61-192 CKV-61-533 Glycol Supply Outboard FCV-61-191 Glycol Return Inboard FCV-61-194 CKV-61-680 Glycol Return Outboard FCV-61-193 Lower Containment ERCW Supply I FCV-67-113 CKV-67-10540 Lower Containment ERCW Suooly FCV-67-107 FCV-67-111 Lower Containment ERCW Return CKV-67-5750 FCV-67-112 FCV-67-89 Lower Containment ERCW Supply CKV-67-1054A FCV-67-83 FCV-67-87 Lower Containment ERCW Return CKV-67-575A FCV-67-88 FCV-67-105 Lower Containment ERCW Supply CKV-67-10548 FCV-67-99 FCV-67-103 Lower Containment ERCW Return CKV-67-5758 FCV-67-104 FCV-67-97 Lower Containment ERCW Supply CKV-67-1054C FCV-67-91 FCV-67-95 Lower Containment ERCW Return CKV-67-575C FCV-67-96 (continued) 5.0-25a Amendment 11 I I I I