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Attachment 1 - TS Developmental Revision I Changes (Mark-Up) for WBN Unit 2
	ML14170A045
Person / Time
Site:	Watts Bar
Issue date:	06/16/2014
From:	; Tennessee Valley Authority
To:	; Office of Nuclear Reactor Regulation
Shared Package
ML14170A054	List: ML14169A525; ML14170A042; ML14170A043; ML14170A044; ML14170A045; ML14170A046;
References
	Download: ML14170A045 (194)
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Definitions 1.1 (continued)

Watts Bar - Unit 2 1.1-1 (developmental)

A 1.0 USE AND APPLICATION 1.1 Definitions

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

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

ACTUATION LOGIC TEST An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices.

AXIAL FLUX DIFFERENCE (AFD)

AFD shall be the difference in normalized flux signals between the top and bottom halves of a two section excore neutron detector.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel so that it responds within the required range and accuracy to known input. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, interlock, display, and trip functions. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION shall include an inplace cross calibration that compares the other sensing elements with the recently installed sensing element.

The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping calibrations or total channel steps so that the entire channel is calibrated.

Definitions 1.1 1.1 Definitions (continued)

(continued)

Watts Bar - Unit 2 1.1-2 (developmental)

AI CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

CHANNEL OPERATIONAL TEST (COT)

A COT shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify the OPERABILITY of required alarm, interlock, display, and trip functions. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or other reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS REPORT (COLR)

The COLR is the unit specific document that provides cycle specific parameter limits for the initial and current reload cycle. These cycle specific parameter limits shall be determined for the initial and each reload cycle in accordance with Specification 5.9.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT I-131 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table E-7 of Regulatory Guide 1.109, Rev. 1, NRC, 1977.

Definitions 1.1 1.1 Definitions (continued)

(continued)

Watts Bar - Unit 2 1.1-3 (developmental)

AI

- AVERAGE DISINTEGRATION ENERGY shall be the average (weighted in proportion to the concentration of each radionuclide in the reactor coolant at the time of sampling) of the sum of the average beta and gamma energies per disintegration (in MeV) for isotopes, other than iodines, with half liveshalf-lives > 15 minutes, making up at least 95% of the total non-iodine activity in the coolant.

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

La The maximum allowable primary containment leakage rate, La, shall be.25% of primary containment air weight per day at the calculated peak containment pressure (Pa).

Definitions 1.1 1.1 Definitions (continued)

(continued)

Watts Bar - Unit 2 1.1-4 (developmental)

AI LEAKAGE LEAKAGE shall be:

a.

Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water injection or leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary-to-secondary LEAKAGE);

b.

Unidentified LEAKAGE All LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE;

c.

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

MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing each master relay and verifying the OPERABILITY of each relay.

The MASTER RELAY TEST shall include a continuity check of each associated slave relay.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

Definitions 1.1 1.1 Definitions (continued)

(continued)

Watts Bar - Unit 2 1.1-5 (developmental)

BI OPERABLE-OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

PCO A pressure control operator (PCO) is a devise, such as a damper that is used to control pressure in an air handling system.

PDMS The Power Distribution Monitoring System (PDMS) is a real-time three dimensional core monitoring system. The system utilizes existing core instrumentation data and an on-line neutronics code to provide surveillance of core thermal limits.

PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation. These tests are:

a.

Described in Chapter 14, Initial Test Program of the FSAR;

b.

Authorized under the provisions of 10 CFR 50.59; or

c.

Otherwise approved by the Nuclear Regulatory Commission.

PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

The PTLR is the unit specific document that provides the RCS pressure and temperature limits for heatup, cooldown, low temperature operation, criticality, and hydrostatic testing as well as heatup and cooldown rates for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.9.6. Plant operation within these operating limits is addressed in LCO 3.4.3, "RCS Pressure and Temperature (P/T) Limits," and LCO 3.4.12, "Cold Overpressure Mitigation System (COMS)."

Definitions 1.1 1.1 Definitions (continued)

(continued)

Watts Bar - Unit 2 1.1-6 (developmental)

A QUADRANT POWER TILT RATIO (QPTR)

QPTR shall be the ratio of the maximum upper excore detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER (RTP)

RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3411 MWt.

REACTOR TRIP SYSTEM (RTS) RESPONSE TIME The RTS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RTS trip setpoint at the channel sensor until loss of stationary gripper coil voltage. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and the methodology for verification have been previously reviewed and approved by the NRC.

SHUTDOWN MARGIN (SDM)

SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a.

All rod cluster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and

b.

In MODES 1 and 2, the fuel and moderator temperatures are changed to the nominal zero power design level.

SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay.

The SLAVE RELAY TEST shall include, as a minimum, a continuity check of associated testable actuation devices.

Definitions 1.1 1.1 Definitions (continued)

Watts Bar - Unit 2 1.1-7 (developmental)

A STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TRIP ACTUATING DEVICE OPERATIONAL TEST (TADOT)

A TADOT shall consist of operating the trip actuating device and verifying the OPERABILITY of required alarm, interlock, display, and trip functions. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

Definitions 1.1 Watts Bar - Unit 2 1.1-8 (developmental)

A Table 1.1-1 (page 1 of 1)

MODES MODE TITLE REACTIVITY CONDITION (keff)

% RATED THERMAL POWER (a)

AVERAGE REACTOR COOLANT TEMPERATURE

(°F) 1 Power Operation 0.99

> 5 NA 2

Startup 0.99

< 5 NA 3

Hot Standby

< 0.99 NA 350 4

Hot Shutdown (b)

< 0.99 NA 350 > Tavg > 200 5

Cold Shutdown (b)

< 0.99 NA

< 200 6

Refueling (c)

NA NA NA (a)

Excluding decay heat.

(b)

All reactor vessel head closure bolts fully tensioned.

(c)

One or more reactor vessel head closure bolts less than fully tensioned.

SDM - Tavg > 200°F 3.1.1 Watts Bar - Unit 2 3.1-1 (developmental)

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

APPLICABILITY:

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit.

A.1 Initiate boration to restore SDM to within limit.

15 minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is > 1.6% k/k.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

SDM - Tavg < 200°F 3.1.2 Watts Bar - Unit 2 3.1-2 (developmental)

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

APPLICABILITY:

MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit.

A.1 Initiate boration to restore SDM to within limit.

15 minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify SDM is 1.0% k/k.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

MTC 3.1.4 Watts Bar - Unit 2 3.1-5 (developmental)

A 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Moderator Temperature Coefficient (MTC)

LCO 3.1.4 The MTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be 0 k/k°F at hot zero power.

APPLICABILITY:

MODE 1 and MODE 2 with keff 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. MTC not within upper limit.

A.1 Establish administrative withdrawal limits for control banks to maintain MTC within limit.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. Required Action and associated Completion Time of Condition A not met.

B.1 Be in MODE 2 with keff < 1.0.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months C. MTC not within lower limit.

C.1 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

MTC 3.1.4 Watts Bar - Unit 2 3.1-6 (developmental)

AI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify MTC is within upper limit Once prior to entering MODE 1 after initial fuel loading and each refueling SR 3.1.4.2 Verify MTC is within 300 ppm Surveillance limit specified in the COLR.

NOTE---------

Not required to be performed until 7 effective full power days (EFPD) after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm Once each cycle SR 3.1.4.3

NOTES----------------------------

1. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.4.3 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.

2. SR 3.1.4.3 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of < 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COLR.

NOTE---------

Not required to be performed until 7 EFPD after reaching the equivalent of an equilibrium RTP-ARO boron concentration of 300 ppm Verify MTC is within lower limit.

Once each cycle

Rod Group Alignment Limits 3.1.5 Watts Bar - Unit 2 3.1-7 (developmental)

A 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Rod Group Alignment Limits LCO 3.1.5 All shutdown and control rods shall be OPERABLE, with all individual indicated rod positions within 12 steps of their group step counter demand position.

APPLICABILITY:

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) untrippable.

A.1.1 Verify SDM is 1.6% k/k.

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

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND A.2 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. One rod not within alignment limits.

B.1 Restore rod to within alignment limits.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR B.2.1.1 Verify SDM is 1.6% k/k.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR B.2.1.2 Initiate boration to restore SDM to within limit.

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

Rod Group Alignment Limits 3.1.5 Watts Bar - Unit 2 3.1-8 (developmental)

AI ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2.2 Reduce THERMAL POWER to < 75% RTP.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND B.2.3 Verify SDM is 1.6% k/k.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B.2.4 Perform SR 3.2.1.1.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.2.5 Perform SR 3.2.2.1.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.2.6 Re-evaluate safety analyses and confirm results remain valid for duration of operation under these conditions 5 days C. Required Action and associated Completion Time of Condition B not met.

C.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months D. More than one rod not within alignment limit.

D.1.1 Verify SDM is 1.6% k/k.

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

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND D.2 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

Rod Group Alignment Limits 3.1.5 Watts Bar - Unit 2 3.1-9 (developmental)

AI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify individual rod positions within alignment limit.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod position deviation monitor is inoperable SR 3.1.5.2 Verify rod freedom of movement (tripability) by moving each rod not fully inserted in the core 10 steps in either direction.

92 days SR 3.1.5.3 Verify rod drop time of each rod, from the fully withdrawn position, is < 2.7 seconds from the beginning of decay of stationary gripper coil voltage to dashpot entry, with:

a.

Tavg 551°F; and

b.

All reactor coolant pumps operating.

Prior to reactor criticality after initial fuel loading and each removal of the reactor head

FQ (Z) 3.2.1 Watts Bar - Unit 2 3.2-1 (developmental)

AI 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (FQ (Z))

LCO 3.2.1 FQ (Z), as approximated by FQ C (Z) and FQ W (Z), shall be within the limits specified in the COLR.

APPLICABILITY:

MODE 1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. FQ C (Z) not within limit.

A.1 Reduce THERMAL POWER 1% RTP for each 1% FQ C (Z) exceeds limit.

15 minutes AND A.2 Reduce Power Range Neutron FluxHigh trip setpoints > 1% for each 1% FQ C (Z) exceeds limit.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months AND A.3 Reduce Overpower T trip setpoints 1% for each 1% FQ C (Z) exceeds limit.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND A.4 Perform SR 3.2.1.1.

Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

FQ (Z) 3.2.1 Watts Bar - Unit 2 3.2-2 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. FQ W (Z) not within limits.

B.1 Reduce AFD limits 1%

for each 1% FQ W (Z) exceeds limit.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months C. Required Action and associated Completion Time not met.

C.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

FQ (Z) 3.2.1 Watts Bar - Unit 2 3.2-3 (developmental)

A SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify FQ C (Z) is within limit.

Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by 10% RTP, the THERMAL POWER at which FQ C (Z) was last verified AND 31 EFPD thereafter (continued)

FQ (Z) 3.2.1 Watts Bar - Unit 2 3.2-4 (developmental)

B SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.1.2

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

If FQ W (Z) is within limits and measurements indicate maximum over z

()

has increased since the previous evaluation of FQ C

(Z):

a.

Increase FQ W (Z) by the appropriate factor specified in the COLR and reverify FQ W (Z) is within limits; or

b.

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

()

has not increased.

Verify FQ W (Z) is within limit.

Once after initial fuel loading and each refueling prior to THERMAL POWER exceeding 75% RTP AND (continued)

FQ (Z) 3.2.1 Watts Bar - Unit 2 3.2-5 (developmental)

A SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued)

Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by 10% RTP, the THERMAL POWER at which FQ W (Z) was last verified AND 31 EFPD thereafter

AFD 3.2.3 Watts Bar - Unit 2 3.2-8 (developmental)

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

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

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

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

APPLICABILITY:

MODE 1 with THERMAL POWER > 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits.

A.1 Reduce THERMAL POWER to < 50% RTP.

30 minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore channel.

7 days AND Once within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter with the AFD monitor alarm inoperable

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-1 (developmental)

A 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.1-1.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with one or more required channels inoperable.

A.1 Enter the Condition referenced in Table 3.3.1-1 for the channel(s).

Immediately B. One Manual Reactor Trip channel inoperable.

B.1 Restore channel to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR B.2.1 Be in MODE 3.

54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND B.2.2 Open reactor trip breakers (RTBs).

55 hours6.365741e-4 days 0.0153 hours 9.093915e-5 weeks 2.09275e-5 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-2 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One channel or train inoperable.

C.1 Restore channel or train to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR C.2 Open RTBs.

49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months D. One Power Range Neutron Flux-High channel inoperable.

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

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

D.1.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND D.1.2 Reduce THERMAL POWER to 75% RTP.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months OR D.2.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND

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

Only required to be performed when the Power Range Neutron Flux input to QPTR is inoperable.

D.2.2 Perform SR 3.2.4.2.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR D.3 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-3 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One channel inoperable.

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

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

E.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR E.2 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months F. THERMAL POWER > P-6 and < P-10, one Intermediate Range Neutron Flux channel inoperable.

F.1 Reduce THERMAL POWER to < P-6.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OR F.2 Increase THERMAL POWER to > P-10.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months G. THERMAL POWER > P-6 and < P-10, two Intermediate Range Neutron Flux channels inoperable.

G.1 Suspend operations involving positive reactivity additions.

Immediately AND G.2 Reduce THERMAL POWER to < P-6.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months H. THERMAL POWER < P-6, one or two Intermediate Range Neutron Flux channels inoperable.

H.1 Restore channel(s) to OPERABLE status.

Prior to increasing THERMAL POWER to > P-6 I. One Source Range Neutron Flux channel inoperable.

I.1 Suspend operations involving positive reactivity additions.

Immediately (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-4 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. Two Source Range Neutron Flux channels inoperable.

J.1 Open RTBs.

Immediately K. One Source Range Neutron Flux channel inoperable.

K.1 Restore channel to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR K.2 Open RTBs.

49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months L. Required Source Range Neutron Flux channel inoperable.

L.1 Suspend operations involving positive reactivity additions.

Immediately AND L.2 Close unborated water source isolation valves.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND L.3 Perform SR 3.1.1.1.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-5 (developmental)

F ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME M. One channel inoperable.

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

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

M.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M.2 Reduce THERMAL POWER to < P-7.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months N. One Reactor Coolant Flow - Low channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

N.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR N.2 Reduce THERMAL POWER to < P-7.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-6 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME O. One Low Fluid Oil Pressure Turbine Trip channel inoperable.

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

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

O.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR O.2 Reduce THERMAL POWER to < P-9.

76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months P. One train inoperable.

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

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

P.1 Restore train to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR P.2 Be in MODE 3.

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-7 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Q. One RTB train inoperable.

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

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing, provided the other train is OPERABLE.

Q.1 Restore train to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR Q.2 Be in MODE 3.

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months R. One channel inoperable.

R.1 Verify interlock is in required state for existing unit conditions.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR R.2 Be in MODE 3.

7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months S. One channel inoperable.

S.1 Verify interlock is in required state for existing unit conditions.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR S.2 Be in MODE 2.

7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-8 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME T. One trip mechanism inoperable for one RTB.

T.1 Restore inoperable trip mechanism to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR T.2.1 Be in MODE 3.

54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND T.2.2 Open RTB.

55 hours6.365741e-4 days 0.0153 hours 9.093915e-5 weeks 2.09275e-5 months U. One Steam Generator Water Level - Low-Low channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

U.1.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND U.1.2 For the affected protection set, set the Trip Time Delay (Ts) to match the Trip Time Delay (Tm).

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR U.2 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-9 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME V. One Vessel T channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

V.1 Set the Trip Time Delay threshold power level for (Ts) and (Tm) to 0% power.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR V.2 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months W. One channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

W.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR W.2 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months X. One channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

X.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR X.2 Reduce THERMAL POWER to < P-7.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-10 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Y. One, two or three Turbine Stop Valve Closure channels inoperable.

Y.1 Place channel(s) in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR Y.2 Reduce THERMAL POWER to < P-9.

76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months Z. Two RTS Trains inoperable.

Z.1 Enter LCO 3.0.3.

Immediately SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2

NOTES----------------------------

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

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

Compare results of calorimetric heat balance calculation to Nuclear Instrumentation System (NIS) channel output.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-11 (developmental)

G SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.3

NOTES----------------------------

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

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

Compare results of the PDMS measurements to NIS AFD.

31 effective full power days (EFPD)

SR 3.3.1.4

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

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

Perform TADOT.

62 days on a STAGGERED TEST BASIS SR 3.3.1.5 Perform ACTUATION LOGIC TEST.

92 days on a STAGGERED TEST BASIS SR 3.3.1.6

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

Required to be performed within 6 days after THERMAL POWER is 50% RTP.

Calibrate excore channels to agree with the PDMS measurements.

92 EFPD (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-12 (developmental)

A SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.7

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

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

Perform COT.

184 days SR 3.3.1.8

NOTES----------------------------

1.

Not required to be performed for Source Range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.

2.

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

NOTE---------

Only required when not performed within previous 31 days Perform COT.

Prior to reactor startup AND Four hours after reducing power below P-10 for intermediate range instrumentation AND Four hours after reducing power below P-6 for source range instrumentation AND Every 31 days thereafter (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-13 (developmental)

A SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.9

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

Verification of setpoint is not required.

Perform TADOT.

92 days SR 3.3.1.10

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

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

Perform CHANNEL CALIBRATION.

18 months SR 3.3.1.11

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

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

18 months SR 3.3.1.12 Perform COT.

18 months SR 3.3.1.13

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

Verification of setpoint is not required.

Perform TADOT.

18 months (continued)

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-14 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.14

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

Verification of setpoint is not required.

Perform TADOT.

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

SR 3.3.1.15

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

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits.

18 months on a STAGGERED TEST BASIS

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-15 (developmental)

F Table 3.3.1-1 (page 1 of 9)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

1.

Manual Reactor Trip 1, 2 2

B SR 3.3.1.13 NA NA 3 (a), 4 (a), 5 (a) 2 C

SR 3.3.1.13 NA NA

2.

Power Range Neutron Flux

a.

High 1, 2 4

D SR 3.3.1.1 111.4% RTP 109% RTP SR 3.3.1.2 SR 3.3.1.7 (b)(c)

SR 3.3.1.11 (b)(c)

SR 3.3.1.15

b.

Low 1 (d), 2 4

E SR 3.3.1.1 27.4% RTP 25% RTP SR 3.3.1.7 (b)(c)

SR 3.3.1.11 (b)(c)

SR 3.3.1.15

3.

Power Range Neutron Flux Rate

a.

High Positive Rate 1, 2 4

E SR 3.3.1.7 (b)(c) 6.3% RTP with time constant 2 sec 5% RTP with time constant 2 sec SR 3.3.1.11 (b)(c)

b.

High Negative Rate - DELETED

4.

Intermediate Range Neutron Flux 1 (d), 2 (e) 2 F, G SR 3.3.1.1 40% RTP 25% RTP SR 3.3.1.8 (b)(c)

SR 3.3.1.11 (b)(c) 2 (f) 2 H

SR 3.3.1.1 40% RTP 25% RTP SR 3.3.1.8 (b)(c)

SR 3.3.1.11 (b)(c)

(continued)

(a) With Reactor Trip Breakers (RTBs) closed and Rod Control System capable of rod withdrawal.

(b) If the as found channel setpoint is outside its predefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(d) Below the P-10 (Power Range Neutron Flux) interlocks.

(e) Above the P-6 (Intermediate Range Neutron Flux) interlocks.

(f) Below the P-6 (Intermediate Range Neutron Flux) interlocks.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-16 (developmental)

G Table 3.3.1-1 (page 2 of 9)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

5.

Source Range Neutron Flux 2 (f) 2 I, J SR 3.3.1.1 1.33 E5 cps 1.0 E5 cps SR 3.3.1.8 (b)(c)

SR 3.3.1.11 (b)(c) 3 (a), 4 (a), 5 (a) 2 J, K SR 3.3.1.1 1.33 E5 cps 1.0 E5 cps SR 3.3.1.8 (b)(c)

SR 3.3.1.11 (b)(c)

SR 3.3.1.15 3 (g), 4 (g), 5 (g) 1 L

SR 3.3.1.1 N/A N/A SR 3.3.1.11 (b)(c)

6.

Overtemperature T 1, 2 4

W SR 3.3.1.1 Refer to Note 1 (Page 3.3-21)

Refer to Note 1 (Page 3.3-21)

SR 3.3.1.3 SR 3.3.1.6 SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

SR 3.3.1.15

7.

Overpower T 1, 2 4

W SR 3.3.1.1 Refer to Note 2 (Page 3.3-22)

Refer to Note 2 (Page 3.3-22)

SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

SR 3.3.1.15

8.

Pressurizer Pressure

a.

Low 1 (h) 4 X

SR 3.3.1.1 1964.8 psig 1970 psig SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

SR 3.3.1.15

b.

High 1, 2 4

W SR 3.3.1.1 2390.2 psig 2385 psig SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

SR 3.3.1.15 (continued)

(a) With Reactor Trip Breakers (RTBs) closed and Rod Control System capable of rod withdrawal.

(b) If the as found channel setpoint is outside its predefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(f) Below the P-6 (Intermediate Range Neutron Flux) interlocks.

(g) With the RTBs open. In this condition, source range Function does not provide reactor trip but does provide indication.

(h) Above the P-7 (Low Power Reactor Trips Block) interlock.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-17 (developmental)

G Table 3.3.1-1 (page 3 of 9)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

9.

Pressurizer Water Level-High 1 (h) 3 X

SR 3.3.1.1 92.7% span 92% span SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

10.

Reactor Coolant Flow -

Low 1 (h) 3 per loop N

SR 3.3.1.1 89.7% flow 90% flow SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

SR 3.3.1.15

11.

Undervoltage RCPs 1 (h) 1 per bus M

SR 3.3.1.9 5112 V 5400 V SR 3.3.1.10 (b)(c)

SR 3.3.1.15

12.

Underfrequency RCPs 1 (h) 1 per bus M

SR 3.3.1.9 56.9 Hz 57.5 Hz SR 3.3.1.10 (b)(c)

SR 3.3.1.15 (continued)

(b) If the as found channel setpoint is outside its predefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(h) Above the P-7 (Low Power Reactor Trips Block) interlock.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-18 (developmental)

G Table 3.3.1-1 (page 4 of 9)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

13. SG Water Level -

Low-Low 1, 2 3/SG U

SR 3.3.1.1 16.4% of narrow range span 17% of narrow range span SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

SR 3.3.1.15 Coincident with:

a)

Vessel T Equivalent to power 50% RTP 1, 2 3

V SR 3.3.1.7 (b)(c)

Vessel T variable input 52.6% RTP Vessel T variable input 50% RTP SR 3.3.1.10 (b)(c)

With a time delay (Ts) if one steam generator is affected 1.01 Ts (Refer to Note 3, Page 3.3-23)

Ts (Refer to Note 3, Page 3.3-23) or A time delay (Tm) if two or more steam generators are affected 1.01 Tm (Refer to Note 3, Page 3.3-23)

Tm (Refer to Note 3, Page 3.3-23) b)

Vessel T Equivalent to power

> 50% RTP with no time delay (Ts and Tm = 0) 1, 2 3

V SR 3.3.1.7 (b)(c)

SR 3.3.1.10 (b)(c)

Vessel T variable input 52.6% RTP Vessel T variable input 50% RTP

14.

Turbine Trip

a.

Low Fluid Oil Pressure 1 (i) 3 O

38.3 psig 45 psig SR 3.3.1.14

b.

Turbine Stop Valve Closure 1 (i) 4 Y

SR 3.3.1.10 1% open 1% open SR 3.3.1.14 (continued)

(b) If the as found channel setpoint is outside its predefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(i) Above the P-9 (Power Range Neutron Flux) interlock.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-19 (developmental)

F Table 3.3.1-1 (page 5 of 9)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

15.

Safety Injection (SI)

Input from Engineered Safety Feature Actuation System (ESFAS) 1, 2 2 trains P

SR 3.3.1.13 NA NA

16.

Reactor Trip System Interlocks

a.

Intermediate Range Neutron Flux, P-6 (1) Enable Manual Block of SR Trip 2 (f) 2 R

SR 3.3.1.11 NA 1.66E-04%

RTP SR 3.3.1.12 (2) Auto Reset (Unblock Manual Block of SR Trip) 2 (f) 2 R

SR 3.3.1.11 7.65E-5%

RTP 0.47E-4% RTP below setpoint SR 3.3.1.12

b.

Low Power Reactor Trips Block, P-7 1

1 per train S

SR 3.3.1.11 NA NA SR 3.3.1.12

c.

Power Range Neutron Flux, P-8 1

4 S

SR 3.3.1.11 50.4% RTP 48% RTP SR 3.3.1.12

d.

Power Range Neutron Flux, P-9 1

4 S

SR 3.3.1.11 52.4% RTP 50% RTP SR 3.3.1.12

e.

Power Range Neutron Flux, P-10 1, 2 4

R SR 3.3.1.11 7.6% RTP and 12.4% RTP 10% RTP SR 3.3.1.12

f.

Turbine Impulse Pressure, P-13 1

2 S

SR 3.3.1.10 12.4%

full-power pressure 10%

full-power pressure SR 3.3.1.12 (continued)

(f) Below the P-6 (Intermediate Range Neutron Flux) interlocks.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-20 (developmental)

A Table 3.3.1-1 (page 6 of 9)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOW-ABLE VALUE NOMINAL TRIP SETPOINT

17.

Reactor Trip Breakers (j) 1, 2 2 trains Q

SR 3.3.1.4 NA NA 3 (a), 4 (a), 5 (a) 2 trains C

SR 3.3.1.4 NA NA

18.

Reactor Trip Breaker Undervoltage and Shunt Trip Mechanisms 1, 2 1 each per RTB T

SR 3.3.1.4 NA NA 3 (a), 4 (a), 5 (a) 1 each per RTB C

SR 3.3.1.4 NA NA

19.

Automatic Trip Logic 1, 2 2 trains P

SR 3.3.1.5 NA NA 3 (a), 4 (a), 5 (a) 2 trains C

SR 3.3.1.5 NA NA (a) With Reactor Trip Breakers (RTBs) closed and Rod Control System capable of rod withdrawal.

(j) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-21 (developmental)

A Table 3.3.1-1 (page 7 of 9)

Reactor Trip System Instrumentation Note 1: Overtemperature T The Overtemperature T Function Allowable Value shall not exceed the following Trip Setpoint by more than 1.2% of T span.

T 1 + 4s 1 + 5sT0 K1 K2 (1 + 1s)

(1 + 2s) T T+ K3P Pf1(I)

Where:

T is measured RCS T, °F.

T0 is the indicated T at RTP, °F.

s is the Laplace transform operator, sec-1.

T is the measured RCS average temperature, °F.

T is the indicated Tavg at RTP, 588.2°F.

P is the measured pressurizer pressure, psig P is the nominal RCS operating pressure, 2235 psig K1 1.16 K2 0.0183/°F K3 = 0.000900/psig 1 33 sec 2 4 sec 4 3 sec 5 3 sec f1(I) =

-2.62{22 + (qt - qb)}

when qt - qb < - 22% RTP 0

when -22% RTP qt - qb 10% RTP 1.96{(qt - qb) - 10}

when qt - qb > 10% RTP Where qt and qb are percent RTP in the upper and lower halves of the core, respectively, and qt + qb is the total THERMAL POWER in percent RTP.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-22 (developmental)

AI Table 3.3.1-1 (page 8 of 9)

Reactor Trip System Instrumentation Note 2: Overpower T The Overpower T Function Allowable Value shall not exceed the following Trip Setpoint by more than 1.0% of T span.

T 1+4s 1+5sT0 K4-K5 (3s)

(1+3s) [T]+K6T-T-f2(I)

Where:

T is measured RCS T, °F.

T0 is the indicated T at RTP, °F.

s is the Laplace transform operator, sec-1.

T is the measured RCS average temperature, °F.

T is the indicated Tavg at RTP, 588.2°F.

K4 1.10 K5 0.02/°F for increasing Tavg K6 0.00162/°F when T > T 0/°F for decreasing Tavg 0/°F when T T 3 5 sec 4

3 sec 5

3 sec f2(I) = 0 for all I.

RTS Instrumentation 3.3.1 Watts Bar - Unit 2 3.3-23 (developmental)

A Table 3.3.1-1 (page 9 of 9)

Reactor Trip System Instrumentation NOTE 3: Steam Generator Water Level Low-Low Trip Time Delay:

Ts = A(P)3 + B(P)2+ C(P)+ D Tm = E(P)3 + F(P)2+ G(P)+ H Where:

P

= Vessel T Equivalent to power (% RTP), P 50% RTP Ts

= Time Delay for Steam Generator Water Level - Low Low Reactor Trip, one Steam Generator affected.

Tm

= Time Delay for Steam Generator Water Level - Low Low Reactor Trip, two or more Steam Generators affected.

A

= -0.0085041 B

= 0.9266400 C

= -33.85998 D

= 474.6060 E

= -0.0047421 F

= 0.5682600 G

= -23.70753 H

= 357.9840

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-24 (developmental)

AI 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.2-1.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with one or more required channels or trains inoperable.

A.1 Enter the Condition referenced in Table 3.3.2-1 for the channel(s) or train(s).

Immediately B. One channel or train inoperable.

B.1 Restore channel or train to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR B.2.1 Be in MODE 3.

54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND B.2.2 Be in Mode MODE 5.

84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-25 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One train inoperable.

C.1

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

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR C.2.1 Be in Mode MODE 3.

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND C.2.2 Be in Mode MODE 5.

60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months D. One channel inoperable.

D.1

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR D.2.1 Be in Mode MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND D.2.2 Be in Mode MODE 4.

84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-26 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One Containment Pressure channel inoperable.

E.1

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

Place channel in bypass.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR E.2.1 Be in Mode MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND E.2.2 Be in Mode MODE 4.

84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months F. One channel or train inoperable.

F.1 Restore channel or train to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR F.2.1 Be in MODE 3.

54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND F.2.2 Be in Mode MODE 4.

60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-27 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. One train inoperable.

G.1

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

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR G.2.1 Be in Mode MODE 3.

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND G.2.2 Be in Mode MODE 4.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. One train inoperable.

H.1

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

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR H.2.1 Be in Mode MODE 3.

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND H.2.2 Be in Mode MODE 4.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-28 (developmental)

BI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I. One Steam Generator Water Level - High High channel inoperable.

I.1

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR I.2.1 Be in Mode MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND I.2.2 Be in Mode MODE 4.

84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months J. One or more Turbine Driven Main Feedwater Pump trip channel(s) inoperable.

J.1 Restore channel to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OR J.2 Be in Mode MODE 3.

54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months K. One channel inoperable.

K.1

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

Place channel in bypass.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR K.2.1 Be in Mode MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND K.2.2 Be in Mode MODE 5.

108 hours0.00125 days 0.03 hours 1.785714e-4 weeks 4.1094e-5 months (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-29 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME L. One P-11 interlock channel inoperable.

L.1 Verify interlock is in required state for existing unit condition.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR L.2.1 Be in Mode MODE 3.

7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND L.2.2 Be in Mode MODE 4.

13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months M. One Steam Generator Water Level - Low-Low channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

M.1.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND M.1.2 For the affected protection set, set the Trip Time Delay (Ts) to match the Trip Time Delay (Tm).

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M.2.1 Be in Mode MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND M.2.2 Be in Mode MODE 4.

84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-30 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME N. One Vessel T channel inoperable.

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

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

N.1 Set the Trip Time Delay threshold power level for (Ts) and (Tm) to 0%

power.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR N.2 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months O. One MSVV Room Water Level High channel inoperable.

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

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

O.1 Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR O.2 Be in MODE 3.

78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-31 (developmental)

B SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.2.2 Perform ACTUATION LOGIC TEST.

92 days on a STAGGERED TEST BASIS SR 3.3.2.3 Perform MASTER RELAY TEST.

92 days on a STAGGERED TEST BASIS SR 3.3.2.4 Perform COT.

184 days SR 3.3.2.5

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

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

Perform SLAVE RELAY TEST.

92 days OR 18 months for Westinghouse type AR and Potter &

Brumfield MDR Series relays (continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-32 (developmental)

FI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.6

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

Verification of relay setpoints not required.

Perform TADOT.

92 days SR 3.3.2.7 Perform SLAVE RELAY TEST on slave relays K603A, K603B, K604A, K604B, K607A, K607B, K609A, K609B, K612A, K625A, and K625B, 18 months SR 3.3.2.8

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

Verification of setpoint not required for manual initiation.

Perform TADOT.

18 months SR 3.3.2.9

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

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

Perform CHANNEL CALIBRATION.

18 months SR 3.3.2.10

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

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

Verify ESFAS RESPONSE TIMES are within limit.

18 months on a STAGGERED TEST BASIS SR 3.3.2.11

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

Verification of setpoint not required.

Perform TADOT.

Once per reactor trip breaker cycle

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-33 (developmental)

FI Table 3.3.2-1 (page 1 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

1.

Safety Injection

a.

Manual Initiation 1, 2, 3, 4 2

B SR 3.3.2.8 NA NA

b.

Automatic Actuation Logic and Actuation Relays 1, 2, 3, 4 2 trains C

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5 SR 3.3.2.7

c.

Containment Pressure - High 1, 2, 3 3

D SR 3.3.2.1 1.6 psig 1.5 psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10

d.

Pressurizer Pressure - Low 1, 2, 3(a) 3 D

SR 3.3.2.1

> 1864.8 psig 1870 psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10

e.

Steam Line Pressure - Low 1, 2, 3(a) 3 per steam line D

SR 3.3.2.1

> 666.6(d) psi g

675(d) psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10

2.

Containment Spray

a.

Manual Initiation 1, 2, 3, 4 2 per train, 2 trains B

SR 3.3.2.8 NA NA

b.

Automatic Actuation Logic and Actuation Relays 1, 2, 3, 4 2 trains C

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5

c.

Containment Pressure -

High High 1, 2, 3 4

E SR 3.3.2.1

< 2.9 psig 2.8 psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10 (a)

Above the P-11 (Pressurizer Pressure) Interlock.

(b)

If the as found channel setpoint is outside its redefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c)

The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(d)

Time constants used in the lead/lag controller are t1 > 50 seconds and t2 < 5 seconds.

(continued)

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-34 (developmental)

FI Table 3.3.2-1 (page 2 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

3.

Containment Isolation

a.

Phase A Isolation

1)

Manual Initiation 1, 2, 3, 4 2

B SR 3.3.2.8 NA NA

2)

Automatic Actuation Logic and Actuation Relays 1, 2, 3, 4 2 trains C

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5 SR 3.3.2.7

3)

Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

b.

Phase B Isolation

1)

Manual Initiation 1, 2, 3, 4 2 per train, 2 trains B

SR 3.3.2.8 NA NA

2)

Automatic Actuation Logic and Actuation Relays 1, 2, 3, 4 2 trains C

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5 SR 3.3.2.7

3)

Containment Pressure -

High High 1, 2, 3 4

E SR 3.3.2.1

< 2.9 psig 2.8 psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10 (continued)

(b)

If the as found channel setpoint is outside its redefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c)

The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-35 (developmental)

FI Table 3.3.2-1 (page 3 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

4.

Steam Line Isolation

a.

Manual Initiation 1, 2 (e), 3 (e) 1/valve F

SR 3.3.2.8 NA NA

b.

Automatic Actuation Logic and Actuation Relays 1, 2 (e), 3 (e) 2 trains G

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5

c.

Containment Pressure -

High High 1, 2 (e), 3 (e) 4 E

SR 3.3.2.1

< 2.9 psig 2.8 psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10

d.

Steam Line Pressure

1)

Low 1, 2 (e), 3 (a)(e) 3 per steam line D

SR 3.3.2.1

> 666.6 (d) psig 675 (d) psig SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10

2)

Negative Rate - High 3 (e)(f) 3 per steam line D

SR 3.3.2.1

< 108.5 (g) psi 100 (g) psi SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10 (continued)

(b)

If the as found channel setpoint is outside its redefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c)

The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(d)

Time constants used in the lead/lag controller are t1 > 50 seconds and t2 < 5 seconds.

(e)

Except when all MSIVs are closed and de-activated.

(f)

Function automatically blocked above P-11 (Pressurizer Interlock) setpoint and is enabled below P-11 when safety injection on Steam Line Pressure Low is manually blocked.

(g)

Time constants utilized in the rate/lag controller are t3 and t4 > 50 seconds.

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-36 (developmental)

FI Table 3.3.2-1 (page 4 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

5.

Turbine Trip and Feedwater Isolation

a.

Automatic Actuation Logic and Actuation Relays 1, 2 (h), 3 (h) 2 trains H

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5

b.

SG Water Level -

High High (P-14) 1, 2 (h), 3 (h) 3 per SG I

SR 3.3.2.1

< 83.1%

82.4%

SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10

c.

Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

d.

North MSV Vault Room Water Level - High 1, 2 (h)(i) 3 per vault room O

SR 3.3.2.6

< 5.31 inches 4 inches SR 3.3.2.9

e.

South MSV Vault Room Water Level - High 1, 2 (h)(i) 3 per vault room O

SR 3.3.2.6

< 4.56 inches 4 inches SR 3.3.2.9 (continued)

(b)

If the as found channel setpoint is outside its redefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c)

The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(h)

Except when all MFIVs, MFRVs, and associated bypass valves are closed and de-activated or isolated by a closed manual valve.

(i)

Mode 2 if Turbine Driven Main Feed Pumps are operating.

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-37 (developmental)

FI Table 3.3.2-1 (page 5 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

6.

Auxiliary Feedwater

a.

Automatic Actuation Logic and Actuation Relays 1, 2, 3 2 trains G

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5

b.

SG Water Level

- Low Low 1, 2, 3 3 per SG M

SR 3.3.2.1

> 16.4%

17.0%

SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10 Coincident with:

1) Vessel T Equivalent to power 50% RTP 1, 2 3

N SR 3.3.2.4 (b) (c)

Vessel T variable input 52.6% RTP Vessel T variable input 50% RTP SR 3.3.2.9 (b) (c)

With a time delay (Ts) if one SG is affected 1.01 Ts (Note 1, Page 3.3-40)

Ts (Note 1, Page 3.3-40) or A time delay (Tm) if two or more SGs are affected 1.01 Tm (Note 1, Page 3.3-40)

Tm (Note 1, Page 3.3-40)

2) Vessel T equivalent to power

> 50% RTP with no time delay (Ts and Tm = 0) 1, 2 3

N SR 3.3.2.4 (b) (c)

Vessel T variable input 52.6% RTP Vessel T variable input 50% RTP SR 3.3.2.9 (b) (c)

c.

Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

(continued)

(b)

If the as found channel setpoint is outside its redefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c)

The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-38 (developmental)

GI Table 3.3.2-1 (page 6 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

6.

Auxiliary Feedwater (continued)

d.

Loss of Offsite Power 1, 2, 3 4 per bus F

Refer to Function 4 of Table 3.3.5-1 for SRs and Allowable Values. Notes (b) and (c) are applicable to SR 3.3.5.2 for this function.

e.

Trip of all Turbine Driven Main Feedwater Pumps 1 (j), 2 (k) 1 per pump J

SR 3.3.2.8 (b)(c)

> 43.3 psig 50 psig SR 3.3.2.9 (b) (c)

SR 3.3.2.10

f.

Auxiliary Feedwater Pumps Train A and B Suction Transfer on Suction Pressure - Low 1, 2, 3 3

F SR 3.3.2.6 A) > 0.5 psig A) 1.2 psig SR 3.3.2.9 (b) (c)

SR 3.3.2.10 B) > 1.33 psi g

B) 2.0 psig

7.

Automatic Switchover to Containment Sump

a.

Automatic Actuation Logic and Actuation Relays 1, 2, 3, 4 2 trains C

SR 3.3.2.2 NA NA SR 3.3.2.3 SR 3.3.2.5

b.

Refueling Water Storage Tank (RWST)

Level - Low 1, 2, 3, 4 4

K SR 3.3.2.1

> 155.6 inche s from Tank Base 158 inches from Tank Base SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10 Coincident with Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

and Coincident with Containment Sump Level - High 1, 2, 3, 4 4

K SR 3.3.2.1

> 37.2 inches above el. 702.8 ft 38.2 inches above el. 702.8 ft SR 3.3.2.4 (b) (c)

SR 3.3.2.9 (b) (c)

SR 3.3.2.10 (continued)

(b)

If the as found channel setpoint is outside its redefined as found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c)

The instrument channel setpoint shall be reset to a value that is within the as left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. The methodologies used to determine the as found and as left tolerances for the NTSP are specified in FSAR Section 7.1.2.

(j)

Entry into Condition J may be suspended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when placing the second Turbine Driven Main Feedwater (TDMFW) Pump in service or removing one of two TDMFW pumps from service.

(k)

When one or more Turbine Driven Main Feedwater Pump(s) are supplying feedwater to steam generators.

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-39 (developmental)

FI Table 3.3.2-1 (page 7 of 8)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE NOMINAL TRIP SETPOINT

8.

ESFAS Interlocks

a.

Reactor Trip, P-4 1, 2, 3 1 per train, 2 trains F

SR 3.3.2.11 NA NA

b.

Pressurizer Pressure, P-11 (1) Unblock (Auto Reset of SI Block) 1, 2, 3 3

L SR 3.3.2.1

< 1975.2 psig 1970 psig SR 3.3.2.4 SR 3.3.2.9 (2) Enable Manual Block of SI 1, 2, 3 3

L SR 3.3.2.1

> 1956.8 psig 1962 psig SR 3.3.2.4 SR 3.3.2.9

ESFAS Instrumentation 3.3.2 Watts Bar - Unit 2 3.3-40 (developmental)

F Table 3.3.2-1 (page 8 of 8)

Engineered Safety Feature Actuation System Instrumentation NOTE 1: Steam Generator Water Level Low-Low Trip Time Delay:

Ts = A(P)3 + B(P)2+ C(P)+ D Tm = E(P)3 + F(P)2+ G(P)+ H Where:

P

= Vessel T Equivalent to power (% RTP), P 50% RTP Ts

= Time Delay for Steam Generator Water Level - Low Low Reactor Trip, one Steam Generator affected.

Tm

= Time Delay for Steam Generator Water Level - Low Low Reactor Trip, two or more Steam Generators affected.

A

= -0.0085041 B

= 0.9266400 C

= -33.85998 D

= 474.6060 E

= -0.0047421 F

= 0.5682600 G

= -23.70753 H

= 357.9840

PAM InstrumentationTHIS SECTION NOT USED 3.3.3 Watts Bar - Unit 2 3.3-41 (developmental)

BI 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) InstrumentationTHIS SECTION NOT USED LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.3-1.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE----------------

Not applicable to Functions 3, 4, 14, and 16.

One or more Functions with one required channel inoperable.

A.1 Restore required channel to OPERABLE status.

30 days B. Required Action and associated Completion Time of Condition A not met.

B.1 Initiate action in accordance with Specification 5.9.8.

Immediately (continued)

PAM InstrumentationTHIS SECTION NOT USED 3.3.3 Watts Bar - Unit 2 3.3-42 (developmental)

BI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions with two required channels inoperable.

OR Functions 3, 4, 14, and 16 with one required channel inoperable.

C.1 Restore one channel to OPERABLE status.

7 days D. Required Action and associated Completion Time of Condition C not met.

D.1 Enter the Condition referenced in Table 3.3.3-1 for the channel.

Immediately E. As required by Required Action D.1 and referenced in Table 3.3.3-1.

E.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required Action D.1 and referenced in Table 3.3.3-1.

F.1 Initiate action in accordance with Specification 5.9.8.

Immediately

PAM InstrumentationTHIS SECTION NOT USED 3.3.3 Watts Bar - Unit 2 3.3-43 (developmental)

BI SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

31 days SR 3.3.3.2

NOTES----------------------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Not applicable to Functions 11 and 16.

Perform CHANNEL CALIBRATION.

18 months SR 3.3.3.3

NOTES----------------------------

1. Verification of relay setpoints not required.

2. Only applicable to Functions 11 and 16.

Perform TADOT.

18 months

PAM InstrumentationTHIS SECTION NOT USED 3.3.3 Watts Bar - Unit 2 3.3-44 (developmental)

HI Table 3.3.3-1 (page 1 of 3)

Post Accident Monitoring Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS /

TRAINS CONDITION REFERENCED FROM REQUIRED ACTION D.1

1)

Intermediate Range Neutron Flux (g) 1(a), 2(b), 3 2

E

2)

Source Range Neutron Flux 2(c), 3 2

E

3)

Reactor Coolant System (RCS) Hot Leg Temperature (T-Hot) 1, 2, 3 1 per loop E

4)

RCS Cold Leg Temperature (T-Cold) 1, 2, 3 1 per loop E

5)

RCS Pressure (Wide Range) 1, 2, 3 3

E

6)

Reactor Vessel Water Level (f) 1, 2, 3 2

F

7)

Containment Sump Water Level (Wide Range) 1, 2, 3 2

E

8)

Containment Lower Comp.

Atm. Temperature 1, 2, 3 2

E

9)

Containment Pressure (Wide Range) (g) 1, 2, 3 2

E

10)

Containment Pressure (Narrow Range) 1, 2, 3 4

E

11)

Containment Isolation Valve Position (g) 1, 2, 3 2 per penetration flow path (d)(i)

E

12)

Containment Radiation (High Range) 1, 2, 3 2 upper containment 2 lower containment F

13)

RCS Pressurizer Level 1, 2, 3 3

E

14)

Steam Generator (SG) Water Level (Wide Range) (g) 1, 2, 3 1/SG E

(continued)

PAM InstrumentationTHIS SECTION NOT USED 3.3.3 Watts Bar - Unit 2 3.3-45 (developmental)

BI Table 3.3.3-1 (page 2 of 3)

Post Accident Monitoring Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS /

TRAINS CONDITION REFERENCED FROM REQUIRED ACTION D.1

15)

Steam Generator Water Level (Narrow Range) 1, 2, 3 3/SG E

16)

AFW Valve Status (j) 1, 2, 3 1 per valve E

17)

Core Exit Temperature-Quadrant 1(f) 1, 2, 3 2 (e)

E

18)

Core Exit Temperature-Quadrant 2(f) 1, 2, 3 2 (e)

E

19)

Core Exit Temperature-Quadrant 3(f) 1, 2, 3 2 (e)

E

20)

Core Exit Temperature-Quadrant 4(f) 1, 2, 3 2 (e)

E

21)

Auxiliary Feedwater Flow 1, 2, 3 2/SG E

22)

Reactor Coolant System Subcooling Margin Monitor (h) 1, 2, 3 2

E

23)

Refueling Water Storage Tank Water Level 1, 2, 3 2

E

24)

Steam Generator Pressure 1, 2, 3 2/SG E

25)

Auxiliary Building Passive Sump Level (j) 1, 2, 3 2

E

PAM InstrumentationTHIS SECTION NOT USED 3.3.3 Watts Bar - Unit 2 3.3-46 (developmental)

BI Table 3.3.3-1 (page 3 of 3)

Post Accident Monitoring Instrumentation (a)

Below the P-10 (Power Range Neutron Flux) interlocks.

(b)

Above the P-6 (Intermediate Range Neutron Flux) interlocks.

(c)

Below the P-6 (Intermediate Range Neutron Flux) interlocks (d)

Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, pressure relief valve, or check valve with flow through the valve secured.

(e)

A channel consists of two core exit thermocouples (CETs).

(f)

The Common Q Post Accident Monitoring System provides these functions on a flat screen display.

(g)

Regulatory Guide 1.97, non-Type A, Category 1 Variables.

(h)

This function is displayed on the Common Q Post Accident Monitoring System flat screen display and digital panel meters.

(i)

Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(j)

Watts Bar specific (not required by Regulatory Guide 1.97) non-Type A Category 1 variable.

Containment Vent Isolation Instrumentation 3.3.6 Watts Bar - Unit 2 3.3-53 (developmental)

H 3.3 INSTRUMENTATION 3.3.6 Containment Vent Isolation Instrumentation LCO 3.3.6 The Containment Vent Isolation instrumentation for each Function in Table 3.3.6-1 shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One radiation monitoring channel inoperable.

A.1 Restore the affected channel to OPERABLE status.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (continued)

Containment Vent Isolation Instrumentation 3.3.6 Watts Bar - Unit 2 3.3-54 (developmental)

H ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more Functions with one or more manual or automatic actuation trains inoperable.

OR Two radiation monitoring channels inoperable.

OR Required Action and associated Completion Time of Condition A not met.

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

One train of automatic actuation logic may be bypassed and Required Action B.1 may be delayed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for Surveillance testing provided the other train is OPERABLE.

B.1 Enter applicable Conditions and Required Actions of LCO 3.6.3, "Containment Isolation Valves," for containment purge and exhaust isolation valves made inoperable by isolation instrumentation.

Immediately

Containment Vent Isolation Instrumentation 3.3.6 Watts Bar - Unit 2 3.3-55 (developmental)

B SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.2

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

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

Perform ACTUATION LOGIC TEST.

92 days on a STAGGERED TEST BASIS SR 3.3.6.3

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

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

Perform MASTER RELAY TEST.

92 days on a STAGGERED TEST BASIS SR 3.3.6.4 Perform COT.

92 days SR 3.3.6.5 Perform SLAVE RELAY TEST.

92 days OR 18 months for Westinghouse type AR and Potter &

Brumfield MDR Series relays (continued)

Containment Vent Isolation Instrumentation 3.3.6 Watts Bar - Unit 2 3.3-56 (developmental)

A SURVEILLANCE REQUIREMENTS (Continued)

SURVEILLANCE FREQUENCY SR 3.3.6.6

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

Verification of setpoint is not required.

Perform TADOT.

18 months SR 3.3.6.7 Perform CHANNEL CALIBRATION.

18 months

Containment Vent Isolation Instrumentation 3.3.6 Watts Bar - Unit 2 3.3-57 (developmental)

HI Table 3.3.6-1 (page 1 of 1)

Containment Vent Isolation Instrumentation FUNCTION REQUIRED CHANNELS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1.

Manual Initiation 2

SR 3.3.6.6 NA

2.

Automatic Actuation Logic and Actuation Relays 2 trains SR 3.3.6.2 SR 3.3.6.3 SR 3.3.6.5 NA

3.

Containment Purge Exhaust Radiation Monitors 2

SR 3.3.6.1 SR 3.3.6.4 SR 3.3.6.7

< 2.8E-02 µCi/cc(b)

(1.14x104 cpm)

4.

Safety Injection Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 1, for all initiation functions and requirements.

PAM Instrumentation 3.3.39 Watts Bar - Unit 2 3.3-41 (developmental)

BI 3.3 INSTRUMENTATION 3.3.3 9 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.39 The PAM instrumentation for each Function in Table 3.3.39-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.3-91.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE----------------

Not applicable to Functions 3, 4, 14, and 16.

One or more Functions with one required channel inoperable.

A.1 Restore required channel to OPERABLE status.

30 days B. Required Action and associated Completion Time of Condition A not met.

B.1 Initiate action in accordance with Specification 5.9.8.

Immediately (continued)

PAM Instrumentation 3.3.39 Watts Bar - Unit 2 3.3-42 (developmental)

BI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions with two required channels inoperable.

OR Functions 3, 4, 14, and 16 with one required channel inoperable.

C.1 Restore one channel to OPERABLE status.

7 days D. Required Action and associated Completion Time of Condition C not met.

D.1 Enter the Condition referenced in Table 3.3.39-1 for the channel.

Immediately E. As required by Required Action D.1 and referenced in Table 3.3.39-1.

E.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required Action D.1 and referenced in Table 3.3.39-1.

F.1 Initiate action in accordance with Specification 5.9.8.

Immediately

PAM Instrumentation 3.3.39 Watts Bar - Unit 2 3.3-43 (developmental)

BI SURVEILLANCE REQUIREMENTS

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

SR 3.3.39.1 and SR 3.3.39.2 apply to each PAM instrumentation Function in Table 3.3.39-1.

SURVEILLANCE FREQUENCY SR 3.3.39.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

31 days R 3.3.39.2

NOTES----------------------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Not applicable to Functions 11 and 16.

Perform CHANNEL CALIBRATION.

18 months SR 3.3.39.3

NOTES----------------------------

1. Verification of relay setpoints not required.

2. Only applicable to Functions 11 and 16.

Perform TADOT.

18 months

PAM Instrumentation 3.3.39 Watts Bar - Unit 2 3.3-44 (developmental)

HI Table 3.3.39-1 (page 1 of 3)

Post Accident Monitoring Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS /

TRAINS CONDITION REFERENCED FROM REQUIRED ACTION D.1

1)

Intermediate Range Neutron Flux (g) 1(a), 2(b), 3 2

E

2)

Source Range Neutron Flux 2(c), 3 2

E

3)

Reactor Coolant System (RCS) Hot Leg Temperature (T-Hot) 1, 2, 3 1 per loop E

4)

RCS Cold Leg Temperature (T-Cold) 1, 2, 3 1 per loop E

5)

RCS Pressure (Wide Range) 1, 2, 3 3

E

6)

Reactor Vessel Water Level (f) 1, 2, 3 2

F

7)

Containment Sump Water Level (Wide Range) 1, 2, 3 2

E

8)

Containment Lower Comp.

Atm. Temperature 1, 2, 3 2

E

9)

Containment Pressure (Wide Range) (g) 1, 2, 3 2

E

10)

Containment Pressure (Narrow Range) 1, 2, 3 4

E

11)

Containment Isolation Valve Position (g) 1, 2, 3 2 per penetration flow path (d)(i)

E

12)

Containment Radiation (High Range) 1, 2, 3 2 upper containment 2 lower containment F

13)

RCS Pressurizer Level 1, 2, 3 3

E

14)

Steam Generator (SG) Water Level (Wide Range) (g) 1, 2, 3 1/SG E

(continued)

PAM Instrumentation 3.3.39 Watts Bar - Unit 2 3.3-45 (developmental)

BI Table 3.3.39-1 (page 2 of 3)

Post Accident Monitoring Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS /

TRAINS CONDITION REFERENCED FROM REQUIRED ACTION D.1

15)

Steam Generator Water Level (Narrow Range) 1, 2, 3 3/SG E

16)

AFW Valve Status (j) 1, 2, 3 1 per valve E

17)

Core Exit Temperature-Quadrant 1(f) 1, 2, 3 2 (e)

E

18)

Core Exit Temperature-Quadrant 2(f) 1, 2, 3 2 (e)

E

19)

Core Exit Temperature-Quadrant 3(f) 1, 2, 3 2 (e)

E

20)

Core Exit Temperature-Quadrant 4(f) 1, 2, 3 2 (e)

E

21)

Auxiliary Feedwater Flow 1, 2, 3 2/SG E

22)

Reactor Coolant System Subcooling Margin Monitor (h) 1, 2, 3 2

E

23)

Refueling Water Storage Tank Water Level 1, 2, 3 2

E

24)

Steam Generator Pressure 1, 2, 3 2/SG E

25)

Auxiliary Building Passive Sump Level (j) 1, 2, 3 2

E

PAM Instrumentation 3.3.39 Watts Bar - Unit 2 3.3-46 (developmental)

BI Table 3.3.39-1 (page 3 of 3)

Post Accident Monitoring Instrumentation (a)

Below the P-10 (Power Range Neutron Flux) interlocks.

(b)

Above the P-6 (Intermediate Range Neutron Flux) interlocks.

(c)

Below the P-6 (Intermediate Range Neutron Flux) interlocks (d)

Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, pressure relief valve, or check valve with flow through the valve secured.

(e)

A channel consists of two core exit thermocouples (CETs).

(f)

The Common Q Post Accident Monitoring System provides these functions on a flat screen display.

(g)

Regulatory Guide 1.97, non-Type A, Category 1 Variables.

(h)

This function is displayed on the Common Q Post Accident Monitoring System flat screen display and digital panel meters.

(i)

Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(j)

Watts Bar specific (not required by Regulatory Guide 1.97) non-Type A Category 1 variable.

RCS Loops - MODE 4 3.4.6 Watts Bar - Unit 2 3.4-9 (developmental)

BI 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops - MODE 4 LCO 3.4.6 Two loops shall be OPERABLE, and consist of either:

a.

Any combination of RCS loops and residual heat removal (RHR) loops, and one loop shall be in operation, when the rod control system is not capable of rod withdrawal; or

b.

Two RCS loops, and both loops shall be in operation, when the rod control system is capable of rod withdrawal.

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

No RCP shall be started with any RCS cold leg temperature less than or equal to the COMS arming temperature specified in the PTLR, unless the secondary side water temperature of each steam generator (SG) is 50°F above each of the RCS cold leg temperatures.

APPLICABILITY:

MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Only one RCS loop OPERABLE.

AND Two RHR loops inoperable.

A.1 Initiate action to restore a second loop to OPERABLE status.

Immediately B. One required RHR loop inoperable.

AND No RCS loops OPERABLE.

B.1 Be in MODE 5.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

RCS Loops - MODE 4 3.4.6 Watts Bar - Unit 2 3.4-10 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop not in operation, and reactor trip breakers closed and Rod Control System capable of rod withdrawal.

C.1 Restore required RCS loop to operation.

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

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months D. Required RCS or RHR loops inoperable.

OR No required RCS or RHR loop in operation D.1 De-energize all CRDMs.

Immediately AND D.2 Suspend all operations involving a reduction of RCS boron concentration.

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

Immediately

RCS Loops - MODE 4 3.4.6 Watts Bar - Unit 2 3.4-11 (developmental)

A SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify two RCS loop are in operation when the rod control system is capable of rod withdrawal.

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

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.3 Verify SG secondary side water levels are greater than or equal to 6% narrow range for required RCS loops.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.4 Verify correct breaker alignment and indicated power are available to the required pump that is not in operation.

7 days

RCS Loops - MODE 5, Loops Filled 3.4.7 Watts Bar - Unit 2 3.4-12 (developmental)

BI 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops - MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a.

One additional RHR loop shall be OPERABLE; or

b.

The secondary side water level of at least two steam generators (SGs) shall be greater than or equal to 6% narrow range.

NOTES------------------------------------------

1.

One required RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

2.

No reactor coolant pump shall be started with one or more RCS cold leg temperatures less than or equal to the COMS arming temperature specified in the PTLR unless the secondary side water temperature of each SG is 50°F above each of the RCS cold leg temperatures.

3.

All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

APPLICABILITY:

MODE 5 with RCS loops filled.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop inoperable.

AND Required SGs secondary side water levels not within limits.

A.1 Initiate action to restore a second RHR loop to OPERABLE status.

Immediately OR A.2 Initiate action to restore required SG secondary side water levels to within limits.

Immediately (continued)

RCS Loops - MODE 5, Loops Filled 3.4.7 Watts Bar - Unit 2 3.4-13 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops inoperable.

OR No RHR loop in operation.

B.1 Suspend all operations involving a reduction of RCS boron concentration.

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

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

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.2 Verify SG secondary side water level is greater than or equal to 6% narrow range in required SGs.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.3 Verify correct breaker alignment and indicated power are available to the required RHR pump that is not in operation.

7 days

Pressurizer Safety Valves 3.4.10 Watts Bar - Unit 2 3.4-18 (developmental)

FI 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings 2410 psig and 2560 psig.

APPLICABILITY:

MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures greater than> the COMS arming temperature specified in the PTLR.

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

The lift settings are not required to be within the LCO limits during MODE 3 and MODE 4 with all RCS cold leg temperatures greater than>

the COMS arming temperature specified in the PTLR for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety valve inoperable.

A.1 Restore valve to OPERABLE status.

15 minutes B. Required Action and associated Completion Time not met.

OR Two or more pressurizer safety valves inoperable.

B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND B.2 Be in MODE 4 with any RCS cold leg temperature less than or equal to < the COMS arming temperature specified in the PTLR.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

Pressurizer Safety Valves 3.4.10 Watts Bar - Unit 2 3.4-19 (developmental)

A SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in accordance with the Inservice Testing Program.

Following testing, lift settings shall be within +/- 1% of the nominal lift setting of 2485 psig.

In accordance with the Inservice Testing Program

COMS 3.4.12 Watts Bar - Unit 2 3.4-23 (developmental)

FI 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Cold Overpressure Mitigation System (COMS)

LCO 3.4.12 A COMS System shall be OPERABLE with a maximum of one charging pump and no safety injection pump capable of injecting into the RCS and the accumulators isolated and either a or b below.

a.

Two RCS relief valves, as follows:

1. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or

2. One PORV with a lift setting within the limits specified in the PTLR and the RHR suction relief valve with a setpoint 436.5 psig and 463.5 psig.

b.

The RCS depressurized and an RCS vent capable of relieving

> 475 gpm water flow.

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

1.

Two charging pumps may be made capable of injecting for less than or equal to one hour for pump swap operations.

2.

Accumulator may be unisolated when accumulator pressure is less than the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

APPLICABILITY:

MODE 4 with any RCS cold leg temperature less than or equal to < the COMS arming temperature specified in the PTLR, MODE 5, MODE 6 when the reactor vessel head is on

COMS 3.4.12 Watts Bar - Unit 2 3.4-24 (developmental)

BI ACTIONS

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

LCO 3.0.4.b is not applicable when entering MODE 4.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more safety injection pumps capable of injecting into the RCS.

A.1 Initiate action to verify no safety injection pumps are capable of injecting into the RCS.

Immediately B. Two or more charging pumps capable of injecting into the RCS.

B.1 Initiate action to verify a maximum of one charging pump is capable of injecting into the RCS.

Immediately C. An accumulator not isolated when the accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

C.1 Isolate affected accumulator.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months D. Required Action and associated Completion Time of Condition C not met.

D.1 Increase RCS cold leg temperature to greater than > the COMS arming temperature specified in the PTLR.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR D.2 Depressurize affected accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

COMS 3.4.12 Watts Bar - Unit 2 3.4-25 (developmental)

BI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One required RCS relief valve inoperable in MODE 4 with any RCS cold leg temperature less than or equal to< the COMS arming temperature specified in the PTLR.

E.1 Restore required RCS relief valve to OPERABLE status.

7 days F. One required RCS relief valve inoperable in MODE 5 or 6.

F.1 Restore required RCS relief valve to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months G. Two required RCS relief valves inoperable.

OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met.

OR COMS inoperable for any reason other than Condition A, B, C, D, E, or F.

G.1 Depressurize RCS and establish RCS vent.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

COMS 3.4.12 Watts Bar - Unit 2 3.4-26 (developmental)

GI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify no safety injection pumps are capable of injecting into the RCS.

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below the COMS arming temperature specified in the PTLR225°F.

AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter SR 3.4.12.2 Verify a maximum of one charging pump is capable of injecting into the RCS.

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below the COMS arming temperature specified in the PTLR225°F.

AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter SR 3.4.12.3 Verify each accumulator is isolated.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

COMS 3.4.12 Watts Bar - Unit 2 3.4-27 (developmental)

GI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.4

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

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

Verify RCS vent open.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked open vent paths AND 31 days for locked open vent paths (continued)

SR 3.4.12.5 Verify PORV block valve is open for each required PORV.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.4.12.6 Verify both RHR suction isolation valves are locked open with operator power removed for the required RHR suction relief valve.

31 days SR 3.4.12.7

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

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

Perform a COT on each required PORV, excluding actuation.

31 days SR 3.4.12.8 Perform CHANNEL CALIBRATION for each required PORV actuation channel.

18 months

COMS 3.4.12 Watts Bar - Unit 2 3.4-28 (developmental)

BI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.5 Verify PORV block valve is open for each required PORV.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.4.12.6 Verify both RHR suction isolation valves are locked open with operator power removed for the required RHR suction relief valve.

31 days SR 3.4.12.7

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

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

Perform a COT on each required PORV, excluding actuation.

31 days SR 3.4.12.8 Perform CHANNEL CALIBRATION for each required PORV actuation channel.

18 months

RCS Specific Activity 3.4.16 Watts Bar - Unit 2 3.4-35 (developmental)

H 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY:

MODES 1 and 2, MODE 3 with RCS average temperature (Tavg) 500°F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT I-131

> 0.265 µCi/gm.

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

LCO 3.0.4.c is applicable.

A.1 Verify DOSE EQUIVALENT I-131 14 µCi/gm.

Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND A.2 Restore DOSE EQUIVALENT I-131 to within limit.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months B. Gross specific activity of the reactor coolant not within limit.

B.1 Perform SR 3.4.16.2.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND B.2 Be in MODE 3 with Tavg < 500°F.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (continued)

RCS Specific Activity 3.4.16 Watts Bar - Unit 2 3.4-36 (developmental)

HI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and associated Completion Time of Condition A not met.

OR DOSE EQUIVALENT I-131

> 14 µCi/gm.

C.1 Be in MODE 3 with Tavg < 500°F.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity

< 100/E µCi/gm.

7 days SR 3.4.16.2

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

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT I-131 specific activity 0.265 µCi/gm.

14 days AND Between 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

RCS Specific Activity 3.4.16 Watts Bar - Unit 2 3.4-37 (developmental)

A SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.16.3

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

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

Determine from a sample taken in MODE 1 after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

184 days

SG Tube Integrity 3.4.17 Watts Bar - Unit 2 3.4-38 (developmental)

GI 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained AND All SG tubes satisfying the tube plugging or repair criteria shall be plugged or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

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

Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes satisfying the tube plugging or repair criteria and not plugged or repaired in accordance with the Steam Generator Program A.1 Verify tube integrity of the affected tube(s) is maintained until the next refueling outage or SG tube inspection 7 days AND A.2 Plug or repair the affected tube(s) in accordance with the Steam Generator Program Prior to entering MODE 4 following the next refueling outage or SG tube inspection B. Required Action and associated Completion Time of Condition A not met OR SG tube integrity not maintained B.1 Be in MODE 3.

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

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months

SG Tube Integrity 3.4.17 Watts Bar - Unit 2 3.4-39 (developmental)

GI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify steam generator tube integrity in accordance with the Steam Generator Program.

In accordance with the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that satisfies the tube plugging or repair criteria is plugged or repaired in accordance with the Steam Generator Program.

Prior to entering MODE 4 following a SG tube inspection

ECCS - Operating 3.5.2 Watts Bar - Unit 2 3.5-3 (developmental)

A 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.

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

1. In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to perform pressure isolation valve testing per SR 3.4.14.1.

2. In MODE 3, the safety injection pumps and charging pumps may be made incapable of injecting to support transition into or from the Applicability of the LCO 3.4.12, Cold Overpressure Mitigation System (COMS) for up to four hours or until the temperature of all the RCS cold legs exceeds 375°F, whichever occurs first.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more trains inoperable.

AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

A.1 Restore train(s) to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B. Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND B.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

ECCS - Operating 3.5.2 Watts Bar - Unit 2 3.5-4 (developmental)

BI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position with power to the valve operator removed.

Number Position Function 2-FCV-63-1 Open RHR Supply 2-FCV-63-22 Open SIS Discharge 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.2.2 Verify each ECCS manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

31 days SR 3.5.2.3 Verify ECCS piping is full of water.

31 days SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow point is greater than or equal to the required developed head.

In accordance with the Inservice Testing Program SR 3.5.2.5 Verify each ECCS 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 signal.

18 months SR 3.5.2.6 Verify each ECCS pump starts automatically on an actual or simulated actuation signal.

18 months (continued)

ECCS - Operating 3.5.2 Watts Bar - Unit 2 3.5-5 (developmental)

BI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, each position stop is in the correct position.

Valve Number CCP Discharge Throttle SI Cold Leg Throttle SI Hot Leg Throttle Valves Valves Valves 2-63-582 2-63-550 2-63-542 2-63-583 2-63-552 2-63-544 2-63-584 2-63-554 2-63-546 2-63-585 2-63-556 2-63-548 18 months SR 3.5.2.8 Verify, by visual inspection, each ECCS train containment sump suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.

18 months

Containment Air Temperature 3.6.5 Watts Bar - Unit 2 3.6-15 (developmental)

AI 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be:

a.

> 85°F and 110°F for the containment upper compartment, and

b.

> 100°F and 120°F for the containment lower compartment.

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

The minimum containment average air temperatures in MODES 2, 3, and 4 may be reduced to 60°F.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air temperature not within limits.

A.1 Restore containment average air temperature to within limits.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months B. Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

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

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months

Containment Air Temperature 3.6.5 Watts Bar - Unit 2 3.6-16 (developmental)

A SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment upper compartment average air temperature is within limits.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.6.5.2 Verify containment lower compartment average air temperature is within limits.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

HMS 3.6.8 Watts Bar - Unit 2 3.6-20 (developmental)

AI 3.6 CONTAINMENT SYSTEMS 3.6.8 Hydrogen Mitigation System (HMS)

LCO 3.6.8 Two HMS trains shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One HMS train inoperable.

A.1 Restore HMS train to OPERABLE status.

7 days OR A.2 Perform SR 3.6.8.1 on the OPERABLE train.

Once per 7 days B. One containment region with no OPERABLE hydrogen ignitorigniter.

B.1 Restore one hydrogen ignitor igniter in the affected containment region to OPERABLE status.

7 days C. Required Action and associated Completion Time not met.

C.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

HMS 3.6.8 Watts Bar - Unit 2 3.6-21 (developmental)

AI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Energize each HMS train power supply breaker and verify 33 ignitors igniters are energized in each train.

92 days SR 3.6.8.2 Verify at least one hydrogen ignitor igniter is OPERABLE in each containment region.

92 days SR 3.6.8.3 Energize each hydrogen ignitor igniter and verify temperature is 1700°F.

18 months

MSSVs 3.7.1 Watts Bar - Unit 2 3.7-1 (developmental)

FI 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)

LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each MSSV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam generators with one MSSV inoperable.

A.1 Reduce THERMAL POWER to 59 58 % RTP.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months B. One or more steam generators with two or more MSSVs inoperable.

B.1 Reduce THERMAL POWER to less than or equal to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND

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

Only required in MODE 1.

B.2 Reduce the Power Range Neutron Flux - High reactor trip setpoint to less than or equal to the Maximum Allowable

% RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

MSSVs 3.7.1 Watts Bar - Unit 2 3.7-2 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and associated Completion Time not met.

OR One or more steam generators with 4 MSSVs inoperable.

C.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND C.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1

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

Only required to be performed in MODES 1 and 2.

Verify each required MSSV lift setpoint per Table 3.7.1-2 in accordance with the Inservice Testing Program. Following testing, lift settings shall be within +/- 1%.

In accordance with the Inservice Testing Program

MSSVs 3.7.1 Watts Bar - Unit 2 3.7-3 (developmental)

AI Table 3.7.1-1 (page 1 of 1)

OPERABLE Main Steam Safety Valves Versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs PER STEAM GENERATOR MAXIMUM ALLOWABLE POWER

(% RTP) 3 4241 2

2625 Table 3.7.1-2 (page 1 of 1)

Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING (psig +/- 3%)

STEAM GENERATOR

1

2

3

4 12-522 12-517 12-512 12-527 1224 12-523 12-518 12-513 12-528 1215 12-524 12-519 12-514 12-529 1205 12-525 12-520 12-515 12-530 1195 12-526 12-521 12-516 12-531 1185

MFIVs and MFRVs and Associated Bypass Valves 3.7.3 Watts Bar - Unit 2 3.7-6 (developmental)

A 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs) and Associated Bypass Valves LCO 3.7.3 Four MFIVs, four MFRVs, and associated bypass valves shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3 except when MFIV, MFRV, or associated bypass valve is closed and de-activated or isolated by a closed manual valve.

ACTIONS

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

Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more MFIVs inoperable.

A.1 Close or isolate MFIV.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND A.2 Verify MFIV is closed or isolated.

Once per 7 days B. One or more MFRVs inoperable.

B.1 Close or isolate MFRV.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.2 Verify MFRV is closed or isolated.

Once per 7 days C. One or more MFIV or MFRV bypass valves inoperable.

C.1 Restore bypass valve to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)

MFIVs and MFRVs and Associated Bypass Valves 3.7.3 Watts Bar - Unit 2 3.7-7 (developmental)

AI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One MFIV and MFRV in the same flow path inoperable.

D.1 Isolate affected flow path.

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

E.1 Restore one MFIV bypass valve or MFRV bypass valve to OPERABLE status.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months F. Required Action and associated Completion Time not met.

EF.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND EF.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the closure time of each MFIV, MFRV, and associated bypass valve is 6.5 seconds on an actual or simulated actuation signal.

In accordance with the Inservice Testing Program or 18 months

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-1 (developmental)

F 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a.

Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System; and

b.

Four diesel generators (DGs) capable of supplying the onsite Class 1E AC Electrical Power Distribution System.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

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

LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite circuit inoperable.

A.1 Perform SR 3.8.1.1 for OPERABLE offsite circuit.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Declare required feature(s) with no offsite power available inoperable when its redundant required feature(s) is inoperable.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery of no offsite power to one train concurrent with inoperability of redundant required feature(s)

AND (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-2 (developmental)

F ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3 Restore offsite circuit to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND 6 days from discovery of failure to meet LCO B. One or more DG(s) in Train A inoperable.

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

B.1 Perform SR 3.8.1.1 for the offsite circuits.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.2 Declare required feature(s) supported by the inoperable DG(s) inoperable when its required redundant feature(s) is inoperable 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature(s)

AND B.3.1 Determine OPERABLE DG(s) is not inoperable due to common cause failure.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR B.3.2 Perform SR 3.8.1.2 for OPERABLE DG(s).

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-3 (developmental)

A ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.4 Restore required DG(s) to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND 6 days from discovery of failure to meet LCO C. Two offsite circuits inoperable.

C.1 Declare required feature(s) inoperable when its redundant required feature(s) is inoperable.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery of Condition C concurrent with inoperability of redundant required features AND C.2 Restore one offsite circuit to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months D. One offsite circuit inoperable.

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

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

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

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

when Condition D is entered with no AC power source to any train.

D.1 Restore offsite circuit to OPERABLE status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR D.2 Restore required DG(s) to OPERABLE status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-4 (developmental)

A ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more required DG(s) in Train A inoperable.

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

E.1 Restore required DGs in Train A to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OR E.2 Restore required DGs in Train B to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months F. Required Action and Associated Completion Time of Condition A. B, C, D, or E not met.

F.1 Be in MODE 3.

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

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. Two offsite circuits inoperable.

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

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

G.1 Enter LCO 3.0.3.

Immediately H. One offsite circuit inoperable.

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

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

H.1 Enter LCO 3.0.3.

Immediately

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-5 (developmental)

AI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each offsite circuit.

7 days SR 3.8.1.2

NOTES----------------------------

1. Performance of SR 3.8.1.7 satisfies this SR.

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

Verify each DG starts from standby conditions and achieves steady state voltage 6800 V and 7260 V, and frequency 58.8 Hz and 61.2 Hz60.0 Hz nominal.

As specified in Table 3.8.1-1 SR 3.8.1.3

NOTES----------------------------

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

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

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

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

Verify each DG is synchronized and loaded and operates for 60 minutes at a load 3960 kW and 4400 kW.

As specified in Table 3.8.1-1 SR 3.8.1.4 Verify each skid mounted day tank contains 218.5 gal of fuel oil.

31 days

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-6 (developmental)

AI (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-7 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.5 Check for and remove accumulated water from each skid mounted day tank.

31 days SR 3.8.1.6 Verify the fuel oil transfer system operates to automatically transfer fuel oil from 7 day storage tank to the skid mounted day tank.

31 days SR 3.8.1.7 Verify each DG starts from standby condition and achieves in 10 seconds, voltage 6800 V, and frequency 58.8 Hz. Verify after DG fast start from standby conditions that the DG achieves steady state voltage 6800 V and 7260 V, and frequency 58.859.8 Hz and 61.2 60.1 Hz.

184 days SR 3.8.1.8

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

For the 2A-A and 2B-B Shutdown Boards, This this Surveillance shall not be performed in MODE 1 or 2.

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

Verify automatic and manual transfer of each 6.9 kV shutdown board power supply from the normal offsite circuit to each alternate offsite circuit.

18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-8 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9

NOTES----------------------------

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

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

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

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 66.75 Hz;

b.

Within 3 seconds following load rejection, the voltage is 6555 V and 7260 V; and

c.

Within 4 seconds following load rejection, the frequency is 58.8 Hz and 61.2 Hz.

18 months SR 3.8.1.10

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

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

Verify each DG operating at a power factor 0.8 and 0.9 does not trip and voltage is maintained 8880 V during and following a load rejection of 3960 kW and 4400 kW and 2970 kVAR and 3300 kVAR.

18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-9 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

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

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

Verify on an actual or simulated loss of offsite power 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 10 seconds,

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

3. maintains steady state voltage 6800 V and 7260 V,

4. maintains steady state frequency 58.859.8 Hz and 61.260.1 Hz, and

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

18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-10 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

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

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

Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each Unit 2 DG auto-starts from standby condition and:

a.

In 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 7260 V, and frequency 58.859.8 Hz and 61.2 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.

18 months SR 3.8.1.13

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

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

Verify each DG's automatic trips are bypassed on automatic or emergency start signal except:

a.

Engine overspeed; and

b.

Generator differential current 18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-11 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14

NOTES----------------------------

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

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

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

Verify each DG operating at a power factor 0.8 and 0.9 operates for 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a.

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

b.

For the remaining hours of the test loaded 3960 kW and 4400 kW and 2970 kVAR and 3300 kVAR.

18 months SR 3.8.1.15

NOTES----------------------------

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 3960 kW and 4400 kW.

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

Verify each DG starts and achieves, in 10 seconds, voltage 6800 V, and frequency 58.8 Hz. Verify after DG fast start from standby conditions that the DG achieves steady state voltage 6800 V and 7260 V, and frequency 58.859.8 Hz and 61.260.1 Hz.

18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-12 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16

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

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

Verify each DG:

a.

Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation.

18 months SR 3.8.1.17

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

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

Verify, DG 2A-A and 2B-B with each Unit 2 DG 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

b.

Automatically energizing the emergency load from offsite power.

18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-13 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.18

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

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

Verify the time delay setting for each sequenced load block is within limits for each accident condition and non-accident condition load sequence.

18 months SR 3.8.1.19

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

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

Verify on an actual or simulated loss of offsite power 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.

DGs of the same power train auto-start from standby condition and:

1. energizes permanently connected loads in 10 seconds,

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

3. achieves steady state voltage:

6800 V and 7260 V,

4. achieves steady state frequency 58.859.8 Hz and 61.260.1 Hz, and

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

18 months (continued)

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-14 (developmental)

AI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 Verify during idle operation that any automatic or emergency start signal disables the idle start circuitry and commands the engine to full speed.

18 months SR 3.8.1.21 Verify when started simultaneously from standby condition, each DG achieves, in 10 seconds, voltage 6800 V and frequency 58.8 Hz. Verify after DG fast start from standby conditions that the DG achieves steady state voltage 6800 V and 7260 V, and frequency 58.859.8 Hz and 61.260.1 Hz.

10 years

AC Sources - Operating 3.8.1 Watts Bar - Unit 2 3.8-15 (developmental)

AI Table 3.8.1-1 (page 1 of 1)

Diesel Generator Test Schedule NUMBER OF FAILURES IN LAST 25 VALID TESTS(a)

FREQUENCY 3

31 days 4

7 days(b)

(but no less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months )

(a) Criteria for determining number of failures and valid tests shall be in accordance with Regulatory Position C.2.1 of Regulatory Guide 1.9, Revision 3, where the number of tests and failures is determined on a per DG basis.

(b) This test frequency shall be maintained until seven consecutive failure free starts from standby conditions and load and run tests have been performed. If, subsequent to the 7 failure free tests, 1 or more additional failures occur, such that there are again 4 or more failures in the last 25 tests, the testing interval shall again be reduced as noted above and maintained until 7 consecutive failure free tests have been performed.

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-21 (developmental)

HI 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 Four channels of vital DC and four Diesel Generator (DG) DC electrical power subsystems shall be OPERABLE.

NOTES-------------------------------------------

1.

Vital Battery V may be substituted for any of the required vital batteries.

2.

Spare Vital Chargers 6-S, 7-S, 8-S, or 9-S may be substituted for required Vital chargers.

3.

Spare DG Chargers 1A1, 1B1, 2A1, or 2B1 may be substituted for required DG chargers.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required vital DC electrical power subsystem inoperablebattery charger inoperable.

A.1 Restore vital DC electrical power subsystem to OPERABLE statusbattery terminal voltage to greater than or equal to the minimum established float voltage.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND A.2 Verify vital battery charger float current

< 2 amps.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND A.3 Restore vital battery charger to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-22 (developmental)

HI (continued)

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-23 (developmental)

HI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and Associated Completion Time of Condition A not metOne required vital battery inoperable.

B.1 AND B.2 Restore vital battery to OPERABLE statusBe in MODE 3.

Be in MODE 5.

2 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours C. One DG DC electrical power subsystem inoperable.One required vital DC channel inoperable for reasons other than Condition A or B..

C.1 Restore DG DC electrical power subsystem to OPRABLE statusRestore vital DC channel to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months D. Required Action and Associated Completion Time of Condition A, B, or C not met.

D.1 Declare associated DG inoperable.Be in MODE 3.

6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months sImmediately AND D.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. One required DG battery charger inoperable.

E.1 Restore DG battery terminal voltage to greater than or equal to the minimum established float voltage.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND E.2 Verify DG battery charger float current < 2 amps.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND E.3 Restore DG battery charger to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-24 (developmental)

HI F. One required DG battery inoperable.

F.1 Restore DG battery to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months (continued)

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-25 (developmental)

H ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. One required DG DC electrical power subsystem inoperable for reasons other than Condition E or F.

G.1 Restore DG DC electrical power subsystem to OPERABLE status 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months H. Required Action and associated Completion Time of Condition E, F, or G not met H.1 Declare associated DG inoperable.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify vital battery terminal voltage is 128 V (132 V for vital battery V) on float chargegreater than or equal to the minimum established float voltage.

7 days SR 3.8.4.2 Verify DG battery terminal voltage is 124 V on float chargegreater than or equal to the minimum established float voltage.

7 days SR 3.8.4.3 Verify for the vital batteries that the alternate feeder breakers to each required battery charger are open.

7 days SR 3.8.4.4 Verify correct breaker alignment and indicated power availability for each DG 125 V DC distribution panel and associated battery charger 7 days (continued)

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-26 (developmental)

HI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.5 Verify no visible corrosion at terminals and connectors for the vital batterieseach vital battery charger supplies > 200 amps at greater than or equal to the minimum established float voltage for

> 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

OR Verify connection resistance for the vital batteries is 80 E-6 ohm for inter-cell connections, 50 E-6 ohm for inter-rack connections, 120 E-6 ohm for inter-tier connections, and 50 E-6 ohm for terminal connections.

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

18 months92 days SR 3.8.4.6 Verify no visible corrosion at terminals and connectors for the DG batteries each DG battery charger supplies > 200 amps at greater than or equal to the minimum established float voltage for

> 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

OR Verify connection resistance for the DG batteries is 80 E-6 ohm for inter-cell connections, 50 E-6 ohm for inter-tier connections, and 50 E-6 ohm for terminal connections.

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

18 months92 days

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-27 (developmental)

HI SR 3.8.4.7

NOTES----------------------------

1. The modified performance discharge test in SR 3.8.4.6 may be performed in lieu of the service test in SR 3.8.4.7 once per 60 months.

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

Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deteriorationcapacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads and any connected nonsafety loads for the design duty cycle when subjected to a battery service test.

18 12 months SR 3.8.4.8 Remove visible terminal corrosion and verify battery cell to cell and terminal connections are coated with anti-corrosion material.

12 months SR 3.8.4.9 Verify connection resistance for the vital batteries is 80 E-6 ohm for inter-cell connections, 50 E-6 ohm for inter-rack connections, 120 E-6 ohm for inter-tier connections, and 50 E-6 ohm for terminal connections.

12 months SR 3.8.4.10 Verify connection resistance for the DG batteries is 80 E-6 ohm for inter-cell connections, 50 E-6 ohm for inter-tier connections, and 50 E-6 ohm for terminal connections.

12 months

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-28 (developmental)

HI SR 3.8.4.11

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

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

Verify each vital battery charger is capable of recharging its associated battery from a service or capacity discharge test while supplying normal loads.

OR Verify each vital battery charger is capable of operating for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months at current limit 220 - 250 amps.

18 months SR 3.8.4.12

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

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

Verify each diesel generator battery charger is capable of recharging its associated battery from a service or capacity discharge test while supplying normal loads.

18 months SR 3.8.4.13

NOTES----------------------------

1. The modified performance discharge test in SR 3.8.4.14 may be performed in lieu of the service test in SR 3.8.4.13 once per 60 months.

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

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

18 months

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-29 (developmental)

HI (continued)

DC Sources - Operating 3.8.4 Watts Bar - Unit 2 3.8-30 (developmental)

HI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.14

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

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

Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.

60 months AND 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating

DC Sources - Shutdown 3.8.5 Watts Bar - Unit 2 3.8-25 (developmental)

HI 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources - Shutdown LCO 3.8.5 Vital DC and Diesel Generator (DG) DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown" and to support the Diesel Generators (DGs) required by LCO 3.8.2, "AC Sources - Shutdown."

NOTES------------------------------------------

1. Vital Battery V may be substituted for any of the required vital batteries.

2. Spare vital chargers 6-S, 7-S, 8-S, or 9-S may be substituted for required vital chargers.

3. Spare DG chargers 1A1, 1B1, 2A1, or 2B1 may be substituted for required DG chargers.

APPLICABILITY:

MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required vital DC electrical power subsystems inoperable.

A.1.1 Declare affected required feature(s) inoperable.

Immediately OR A.2.1 Suspend CORE ALTERATIONS.

Immediately AND (continued)

DC Sources - Shutdown 3.8.5 Watts Bar - Unit 2 3.8-26 (developmental)

H ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.2 Suspend movement of irradiated fuel assemblies.

Immediately AND A.2.3 Initiate action to suspend operations involving positive reactivity additions.

Immediately AND A.2.4 Initiate action to restore required vital DC electrical power subsystems to OPERABLE status.

Immediately B. One or more required DG DC electrical power subsystems inoperable.

B.1 Declare associated DG inoperable.

Immediately

DC Sources - Shutdown 3.8.5 Watts Bar - Unit 2 3.8-27 (developmental)

HI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1

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

The following SRs are not required to be performed:

SR 3.8.4.511, SR 3.8.4.612, SR 3.8.4.13, and SR 3.8.4.714.

For DC sources required to be OPERABLE, the following SRs are applicable:

SR 3.8.4.1 SR 3.8.4.26 SR 3.8.4.311 SR 3.8.4.42 SR 3.8.4.57 SR 3.8.4.612 SR 3.8.4.73 SR 3.8.4.4 SR 3.8.4.8 SR 3.8.4.9 SR 3.8.4.13 SR 3.8.4.14 SR 3.8.4.5 SR 3.8.4.10 In accordance with applicable SRs

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-28 (developmental)

HI 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for 125 V vital batteries and 125 V diesel generator (DG) batteries shall be within the limits of Table 3.8.6-1.

APPLICABILITY:

When associated DC electrical power subsystems and DGs are required to be OPERABLE.

ACTIONS

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

Separate Condition entry is allowed for each battery bank.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries with one or more battery cell parameters not within Category A or B limitsrequired vital battery with one or more battery cells float voltage < 2.07 V.

A.1 Verify pilot cells electrolyte level and float voltage meet Table 3.8.6-1 Category C limitsPerform SR 3.8.4.1.

2 1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND A.2 Verify battery cell parameters meet Table 3.8.6-1 Category C limitsPerform SR 3.8.6.1.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND Once per 7 days thereafter AND A.3 Restore battery cell parameters to Category A and B limits of Table 3.8.6-1Restore affected cell float voltage

> 2.07 V.

31 days24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-29 (developmental)

HI B. Required Action and associated Completion Time of Condition A not metOne required vital battery with float current

> 2 amps.

OR One or more batteries with average electrolyte temperature of the representative cells < 60oF for vital batteries and <

50oF for DG batteries.

OR B. One or more batteries with one or more battery cell parameters not within Category C values.

B.1 Declare associated battery inoperablePerform SR 3.8.4.1.

Immediately2 hours AND B.2 Restore vital battery float current to < 2 amps.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-30 (developmental)

HI ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One required DG battery with one or more battery cells float voltage < 2.07 V.

C.1 Perform SR 3.8.4.2.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND C.2 Perform SR 3.8.6.2.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND C.3 Restore affected cell float voltage > 2.07 V.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months D. One required DG battery with float current > 1 amp.

D.1 Perform SR 3.8.4.2.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND D.2 Restore DG battery float current to < 2 amps.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

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

Required Action E.2 shall be completed if electrolyte level was below the top of plates.

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

Required Actions E.1 and E.2 are only applicable if electrolyte level was below the top of plates.

E. One required battery with one or more cells with electrolyte level less than minimum established design limits.

E.1 Restore electrolyte levels to above top of plates.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months AND E.2 Verify no evidence of leakage.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND E.3 Restore electrolyte level to greater than or equal to minimum established design limits.

31 days (continued)

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-31 (developmental)

H ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. One required battery with pilot cell electrolyte temperature less than minimum established design limits.

F.1 Restore battery pilot cell temperature to greater than or equal to minimum established design limits.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months G. More than one required vital batteries with battery parameters not within limits.

OR More than one required DG batteries with battery parameters not within limits.

G.1 Restore battery parameters to within limits.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months H. Required Action and associated Completion Time of Condition A, B, C, D, E, F, or G not met.

OR One required vital battery with one or more battery cells float voltage < 2.07 V and float current > 2 amps.

OR One required DG battery with one or more battery cells float voltage < 2.07 V and float current > 2 amps.

H.1 Declare associate battery inoperable Immediately

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-32 (developmental)

HI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1

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

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

Verify battery cell parameters meet Table 3.8.6-1 Category A limitseach vital battery float current is

< 2 amps.

7 days SR 3.8.6.2

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

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

Verify battery cell parameters meet Table 3.8.6-1 Category B limitseach DG battery float current is

< 1 amp.

7 92 days AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after a battery discharge < 110 V for vital batteries (113.5 V for vital battery V) or 106.5 V for DG batteries AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after a battery overcharge > 150 V for vital batteries (155 V for vital battery V) or 145 V for DG batteries SR 3.8.6.3 Verify average electrolyte temperature of representative cells is 60oF for vital batteries and 50oF for the DG batterieseach required vital and DG battery pilot cell float voltage is > 2.07 V.

31 92 days

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-33 (developmental)

HI SR 3.8.6.4 Verify each required vital and DG battery connected cell electrolyte level is greater than or equal to minimum established design limits.

31 days SR 3.8.6.5 Verify each required vital and DG battery pilot cell temperature is greater than or equal to minimum established design limits.

31 days SR 3.8.6.6 Verify each required vital and DG battery connected cell float voltage is > 2.07 V.

92 days (continued)

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-34 (developmental)

HI SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.7

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

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

Verify battery capacity is > 80% of the manufacturers rating when subjected to a performance discharge test or a modified performance discharge test.

60 months AND 12 months when battery shows degradation, or has reached 85% of the expected life with capacity < 100% of manufacturers rating AND 24 months when battery has reached 85% of the expected life with capacity

> 100% of manufacturers rating

Battery Cell Parameters 3.8.6 Watts Bar - Unit 2 3.8-35 (developmental)

I Table 3.8.6-1 (page 1 of 1)

Battery Cell Parameters Requirements PARAMETER CATEGORY A:

LIMITS FOR EACH DESIGNATED PILOT CELL CATEGORY B:

LIMITS FOR EACH CONNECTED CELL CATEGORY C:

ALLOWABLE LIMIT FOR EACH CONNECTED CELL Electrolyte Level

> Minimum level indication mark, and 1/4 inch above maximum level indication mark (a)

Above top of plates, and not overflowing Float Voltage 2.13 V 2.13 V

> 2.07 V Specific Gravity (b)(c) 1.200 1.195 AND Average of all connected cells

> 1.205 Not more than 0.020 below average of all connected cells AND Average of all connected cells 1.195 (a)

It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during equalizing charges provided it is not overflowing.

(b)

Corrected for electrolyte temperature and level. Level correction is not required, however, when battery charging is < 2 amps when on float charge for vital batteries and < 1.0 amp for DG batteries.

(c)

A battery charging current of < 2 amps when on float charge for vital batteries and < 1.0 amp for DG batteries is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 31 days. When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 31 day allowance.

Decay Time 3.9.10 Watts Bar - Unit 2 3.9-13 (developmental)

HI 3.9 REFUELING OPERATIONS 3.9.10 Decay Time LCO 3.9.10 The reactor shall be subcritical for > 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months .

APPLICABILITY:

During movement of irradiated fuel assemblies within the containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor subcritical for

< 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months .

A.1 Suspend all operations involving movement of irradiated fuel assemblies within the containment.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.10.1 Verify the reactor has been subcritical for

> 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months by confirming the date and time of subcriticality.

Prior to movement of irradiated fuel in the reactor vessel.

Design Features 4.0 (continued)

Watts Bar - Unit 2 4.0-1 (developmental)

C 4.0 DESIGN FEATURES 4.1 Site 4.1.1 Site and Exclusion Area Boundaries The site and exclusion area boundaries shall be as shown in Figure 4.1-1.

4.1.2 Low Population Zone (LPZ)

The LPZ shall be as shown in Figure 4.1-2 (within the 3-mile circle).

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 193 fuel assemblies. Each assembly shall consist of a matrix of Zirlo fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO2) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 57 control rod assemblies. The control material shall be silver indium cadmium as approved by the NRC.

Design Features 4.0 4.0 DESIGN FEATURES (continued)

(continued)

Watts Bar - Unit 2 4.0-2 (developmental)

HI 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks (shown in Figure 4.3-1) are designed and shall be maintained with:

a.

Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent (wt%);

b.

keff < 0.95 if fully flooded with unborated water, which, includes an allowance for uncertainties as described in Sections 4.3.2.7 and 9.1 of the FSAR;

c.

Distances between fuel assemblies are a nominal 10.375 inch center-to-center spacing in the twenty-four flux trap rack modules.

d.

Fuel assemblies with initial enrichments less than a maximum of 5 wt% U-235 enrichment (nominally 4.95 +/- 0.05 wt% U-235) may be stored in the spent fuel racks in any one of four arrangements with specific limits as identified below:

1. Fuel assemblies may be stored in the racks in an all cell arrangement provided the burnup of each assembly is in the acceptable domain identified in Figure 4.3-3, depending upon the specified initial enrichment.

2. New and spent fuel assemblies may be stored in a checkerboard arrangement of 2 new and 2 spent assemblies, provided that each spent fuel assembly has accumulated a minimum burnup in the acceptable domain identified in Figure 4.3-4.

3. New fuel assemblies may be stored in 4-cell arrays with 1 of the 4 cells remaining empty of fuel (i.e. containing only water or water with up to 75 percent by volume of non-fuel bearing material).

Design Features 4.0 4.0 DESIGN FEATURES (continued)

Watts Bar - Unit 2 4.0-3 (developmental)

A 4.3 Fuel Storage (continued)

4. New fuel assemblies with a minimum of 32 integral fuel burnable absorber (IFBA) rods may be stored without further restriction, provided the loading of ZrB2 in the coating of each IFBA rod is minimum of 1.25x (1.9625mg/in).

A water cell is less reactive than any cell containing fuel and therefore a water cell may be used at any location in the loading arrangements.

A water cell is defined as a cell containing water or non-fissile material with no more than 75 percent of the water displaced.

4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a.

Fuel assemblies having a maximum enrichment of 5.0 weight percent U-235 and shall be maintained with the arrangement of 120 storage locations shown in Figure 4.3-2;

b.

keff 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the FSAR;

c.

keff 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in Section 9.1 of the FSAR; and

d.

A nominal 21-inch center to center distance between fuel assemblies placed in the storage racks.

4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below Elevation 747 feet - 1 1/2 inches.

4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 1386 fuel assemblies in 24 flux trap rack modules.

Design Features 4.0 (continued)

Watts Bar - Unit 2 4.0-4 (developmental)

A FIGURE 4.1-1 (PAGE 1 OF 1)

SITE AND EXCLUSION AREA BOUNDARIES

Design Features 4.0 (continued)

Watts Bar - Unit 2 4.0-5 (developmental)

A FIGURE 4.1-2 (PAGE 1 OF 1)

LOW POPULATION ZONE

Design Features 4.0 (continued)

Watts Bar - Unit 2 4.0-6 (developmental)

A FLUX TRAP RACK, TYPICAL FUEL CASK LOADING PIT FIGURE 4.3-1 SPENT FUEL STORAGE RACKS PLAN SPENT FUEL POOL SOUTH WALL WEST WALL

Design Features 4.0 (continued)

Watts Bar - Unit 2 4.0-7 (developmental)

A FIGURE 4.3-2 NEW FUEL STORAGE RACK LOADING PATTERN

Design Features 4.0 (continued)

Watts Bar - Unit 2 4.0-8 (developmental)

H FIGURE 4.3-3 MINIMUM REQUIRED BURNUP FOR UNRESTRICTED STORAGE OF FUEL OF VARIOUS INITIAL ENRICHMENTS ACCEPTABLE BURNUP DOMAIN UNACCEPTABLE BURNUP DOMAIN Initial Enrichment wt% U-235 Burnup, MWD/kgU ACCEPTABLE BURNUP DOMAIN UNACCEPTABLE BURNUP DOMAIN Initial Enrichment wt% U-235 Burnup, MWD/kgU

Design Features 4.0 Watts Bar - Unit 2 4.0-9 (developmental)

H FIGURE 4.3-4 MINIMUM REQUIRED BURNUP FOR A CHECKERBOARD ARRANGEMENT OF 2 SPENT AND 2 NEW FUEL ASSEMBLIES OF 5 wt% U-235 ENRICHMENT (MAXIMUM)

ACCEPTABLE BURNUP DOMAIN UNACCEPTABLE BURNUP DOMAIN Initial Enrichment wt% U-235 Burnup, MWD/kgU ACCEPTABLE BURNUP DOMAIN UNACCEPTABLE BURNUP DOMAIN Initial Enrichment wt% U-235 Burnup, MWD/kgU

Responsibility 5.1 Watts Bar - Unit 2 5.0-1 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Site Vice-President shall be responsible for overall activities of the site, while the Plant Manager shall be responsible for overall unit operation. The Site Vice-President and the Plant Manager shall delegate in writing the succession to this responsibility during his absence.

The Plant Manager or his designee shall approve, prior to implementation, each proposed test, experiment or modification to systems or equipment that affect nuclear safety.

5.1.2 The Shift Manager (SM) shall be responsible for the control room command function. During any absence of the SM from the control room while the unit is in MODE 1, 2, 3, or 4, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function.

During any absence of the SM from the control room while the unit is in MODE 5 or 6, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

Organization 5.2 (continued)

Watts Bar - Unit 2 5.0-2 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a.

Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements shall be documented in the Nuclear Power Organization Topical Report (TVA-NPOD 89-A);

b.

The Plant Manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c.

The Site Vice-President shall have responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and

d.

The individuals who train the operating staff, carry out radiological controls, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

Organization 5.2 5.2 Organization (continued)

Watts Bar - Unit 2 5.0-3 (developmental)

B 5.2.2 Unit Staff The unit staff organization shall include the following:

a.

A non-licensed operator shall be assigned to each reactor containing fuel and an additional non-licensed operator shall be assigned for each control room from which a reactor is being operated in MODES 1, 2, 3, or 4.

b.

The shift crew composition may be less than the minimum requirements of 10 CFR 50.54(m)(2)(i) and Specifications 5.2.2.a and 5.2.2.f for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absences of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

c.

A radiological controls technician shall be on site when fuel is in the reactor.

The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

d.

Deleted

e.

The Operations Superintendent shall have a valid SRO license on this unit.

f.

An individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. This individual shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on shift (Generic Letter 86-04 dated 02/13/86).

Unit Staff Qualifications 5.3 Watts Bar - Unit 2 5.0-4 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications for comparable positions, as specified in TVA Nuclear Quality Assurance Plan (TVA-NQA-PLN89-A).

5.3.2 For the purpose of 10 CFR 55.4, a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1, perform the functions described in 10 CFR 50.54 (m).

Training 5.4 Watts Bar - Unit 2 5.0-5 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.4 Training (removed from Technical Specifications)

Reviews and Audits 5.5 Watts Bar - Unit 2 5.0-6 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.5 Reviews and Audits (removed from Technical Specifications)

TS Bases Control Program 5.6 Watts Bar - Unit 2 5.0-7 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.6 Technical Specifications (TS) Bases Control Program This Program provides a means for processing changes to the Bases of these Technical Specifications.

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

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

a.

A change in the TS incorporated in the license; or

b.

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

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

5.6.4 Proposed changes that meet the criteria of Specification 5.6.2 shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

Procedures, Programs, and Manuals 5.7 (continued)

Watts Bar - Unit 2 5.0-8 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.7 Procedures, Programs, and Manuals 5.7.1 Procedures 5.7.1.1 Scope Written procedures shall be established, implemented, and maintained covering the following activities:

a.

The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b.

The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737, Supplement 1 (Generic Letter 82-33);

c.

Quality assurance for effluent and environmental monitoring;

d.

Fire Protection Program implementation; and

e.

All programs specified in Specification 5.7.2.

5.7.1.2 Review and Approval (removed from Technical Specifications) 5.7.1.3 Temporarily Approved Changes (removed from Technical Specifications)

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar - Unit 2 5.0-9 (developmental)

A 5.7.2 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.7.2.1 (removed from Technical Specifications) 5.7.2.2 (removed from Technical Specifications) 5.7.2.3 Offsite Dose Calculation Manual (ODCM)

a.

The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b.

The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating and Radioactive Effluent Release Reports required by Specifications 5.9.2 and 5.9.3.

Licensee initiated changes to the ODCM:

a.

Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

1.

sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s),

2.

a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

b.

Shall become effective after the approval of the Plant Manager; and

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar - Unit 2 5.0-10 (developmental)

A 5.7.2.3 Offsite Dose Calculation Manual (ODCM) (continued)

c.

Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

5.7.2.4 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include Containment Spray, Safety Injection, Residual Heat Removal, Chemical and Volume Control, Reactor Coolant System Sampling, and Waste Gas. The program shall include the following:

a.

Preventive maintenance and periodic visual inspection requirements; and

b.

Integrated leak test requirements for each system at least once per 18 months.

The provisions of SR 3.0.2 are applicable.

5.7.2.5 (removed from Technical Specifications) 5.7.2.6 (removed from Technical Specifications)

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar - Unit 2 5.0-11 (developmental)

A 5.7.2.7 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable.

The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a.

Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM;

b.

Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to 10 times the concentration values in 10 CFR 20.1001-20.2402, Appendix B, Table 2, Column 2;

c.

Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

d.

Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e.

Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least every 31 days;

f.

Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar - Unit 2 5.0-12 (developmental)

AI 5.7.2.7 Radioactive Effluent Controls Program (continued)

g.

Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be in accordance with the following:

1. For noble gases: a dose rate 500 mrem/yr to the whole body and a dose rate 3000 mrem/yr to the skin, and

2. For idodine-131, idodine-133, tritium, and all radionuclides in particulate form with halfliveshalf lives greater than 8 days: a dose rate 1500 mrem/yr to any organ.

h.

Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;

i.

Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and

j.

Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.

5.7.2.8 (removed from Technical Specifications) 5.7.2.9 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Section 5.2.1.5, cyclic and transient occurrences to ensure that components are maintained within the design limits.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar - Unit 2 5.0-13 (developmental)

A 5.7.2.11 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a.

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

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

b.

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

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar-Unit 2 5.0-14 (developmental)

GI 5.7.2.12 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging or repair of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged, to confirm that the performance criteria are being met.

b.

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

1.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar-Unit 2 5.0-15 (developmental)

GI 5.7.2.12 Steam Generator (SG) Program (continued)

2.

Accident induced leakage performance criterion: The primary-to-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 exceed1 gpm per SG, except for specific types of degradation at specific locations as described in paragraph c.

of the Steam Generator Program.

3.

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

c.

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

d.

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

1.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar-Unit 2 5.0-16 (developmental)

GI 5.7.2.12 Steam Generator (SG) Program (continued)

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar-Unit 2 5.0-17 (developmental)

AI 5.7.2.13 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a.

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

b.

Identification of the procedures used to measure the values of the critical variables;

c.

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

d.

Procedures for the recording and management of data; Secondary Water Chemistry Program (continued)

e.

Procedures defining corrective actions for all off control point chemistry conditions; and

f.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

(continued)

Watts Bar-Unit 2 5.0-18 (developmental)

HI 5.7.2.14 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in accordance with Regulatory Guide 1.52, Revision 2; ASME N510-1989, and the exceptions noted for each ESF system in Tables 6.5-1, 6.5-2, 6.5-3, and 6.5-4 of the FSAR.

a.

Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass within acceptance criterion when tested in accordance with Regulatory Guide 1.52, Revision 2, the exceptions noted for each ESF system in Tables 6.5-1, 6.5-2, 6.5-3, and 6.5-4 of the FSAR, and ASME N510-1989 at the system flowrate specified below.

ESF VENTILATION SYSTEM ACCEPTANCE CRITERIA FLOW RATE Emergency Gas Treatment

< 0.05%

4,000 cfm +/-+ 10%

Auxiliary Building Gas Treatment

< 0.05%

9,000 cfm +/-+ 10%

Control Room Emergency

< 1.00%

4,000 cfm +/-+ 10%

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-19 (developmental)

HI 5.7.2.14 Ventilation Filter Testing Program (VFTP) (continued)

b.

Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass within acceptance criterion when tested in accordance with Regulatory Guide 1.52, Revision 2, the exceptions noted for each ESF system in Tables 6.5-1, 6.5-2, 6.5-3, and 6.5-4 of the FSAR, and ASME N510-1989 at the system flowrate specified below.

ESF VENTILATION SYSTEM ACCEPTANCE CRITERIA FLOW RATE Emergency Gas Treatment

< 0.05%

4,000 cfm +/-+ 10%

Auxiliary Building Gas Treatment

< 0.05%

9,000 cfm +/-+ 10%

Control Room Emergency

< 1.00%

4,000 cfm +/-+ 10%

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-20 (developmental)

HI 5.7.2.14 Ventilation Filter Testing Program (VFTP) (continued)

c.

Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, and the exceptions noted for each ESF system in Tables 6.5-1, 6.5-2, 6.5-3, and 6.5-4 of the FSAR, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30°C and greater than or equal to the relative humidity specified below.

ESF VENTILATION SYSTEM METHYL IODIDE PENETRATION RELATIVE HUMIDITY Emergency Gas Treatment

< 0.175%

70%

Auxiliary Building Gas Treatment

< 0.175%

70%

Control Room Emergency

< 1.0%

70%

d.

Demonstrate for each of the ESF systems that the pressure drop across the entire filtration unit is less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, the exceptions noted for each ESF system in Tables 6.5-1, 6.5-2, 6.5-3, and 6.5-4 of the FSAR, and ASME N510-1989 at the system flowrate specified below.

ESF VENTILATION SYSTEM PRESSURE DROP FLOW RATE Emergency Gas Treatment

< 7.6 inches water 4,000 cfm +/-+ 10%

Auxiliary Building Gas Treatment

< 7.6 inches water 9,000 cfm +/-+ 10%

Control Room Emergency

< 3.5 inches water 4,000 cfm +/-+ 10%

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar - Unit 2 5.0-21 (developmental)

AI 5.7.2.14 Ventilation Filter Testing Program (VFTP) (continued)

e.

Demonstrate that the heaters for each of the ESF systems dissipate the value specified below when tested in accordance with ASME N510-1989.

ESF VENTILATION SYSTEM AMOUNT OF HEAT Emergency Gas Treatment 20 +/-+ 2.0 kW Auxiliary Building Gas Treatment 50 +/-+ 5.0 kW The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.7.2.15 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Waste Gas Holdup System, the quantity of radioactivity contained in gas storage tanks and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.

The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, Postulated Radioactive Release due to Waste Gas System Leak or Failure. The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, Postulated Radioactive Release due to Tank Failures.

The program shall include:

a.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-22 (developmental)

A 5.7.2.15 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

b.

A surveillance program to ensure that the quantity of radioactivity contained in each gas storage tank is less than the amount that would result in a whole body exposure of > 0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and

c.

A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is less than the amount that would result in concentrations less than the limits of 10 CFR 20.1302(b)(2)(i), at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

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

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

a.

Acceptability of new fuel oil for use prior to addition to the 7 day storage tanks by determining that the fuel oil has:

1.

an API gravity or an absolute specific gravity within limits,

2.

a flash point and kinematics viscosity within limits for ASTM 2D fuel oil, and

3.

a clear and bright appearance with proper color;

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-23 (developmental)

A 5.7.2.16 Diesel Fuel Oil Testing Program (continued)

b.

Other properties for ASTM 2D fuel oil are within limits within 31 days following sampling and addition to the 7 day storage tanks; and

c.

Total particulate concentration of the fuel oil in each of the four interconnected tanks which constitute a 7 day storage tank is 10 mg/l when tested every 31 days in accordance with ASTM D-2276, Method A-2 or A-3.

5.7.2.17 (removed from Technical Specifications) 5.7.2.18 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists.

Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

a.

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

b.

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

c.

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

d.

Other appropriate limitations and remedial or compensatory actions.

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-24 (developmental)

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

The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 15.0 psig.

The maximum allowable containment leakage rate, La, at Pa, is 0.25%

of the primary containment air weight per day.

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals Watts Bar-Unit 2 5.0-25 (developmental)

HI 5.7.2.19 Containment Leakage Rate Testing Program (continued)

Leakage rate acceptance criteria are:

a.

Containment overall leakage rate acceptance criterion is 1.0 La.

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

b.

Air lock testing acceptance criteria are:

1. Overall air lock leakage rate is 0.05 La when tested at >

Pa.

2. For each door, leakage rate is 0.01 La when pressurized to 6 psig.

The provisions of SR 3.0.2 do not apply to the test frequencies specified in the Containment Leakage Rate Testing Program.

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

5.7.2.20 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Ventilation System (CREVS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of the applicable regulatory requirement {i.e., 5 rem Total Effective Dose Equivalent (TEDE) for a fuel handling accident or 5 rem whole body or its equivalent to any part of the body} for the duration of the accident. The program shall include the following elements:

a.

The definition of the CRE and the CRE boundary.

b.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals Watts Bar-Unit 2 5.0-26 (developmental)

A 5.7.2.20 Control Room Envelope Habitability Program (continued)

c.

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

d.

Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CREVS, operating at the flow rate defined in the Ventilation Filter Testing Program (VFTP), at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 18 month assessment of the CRE boundary.

e.

The quantitative limits on unfiltered air inleakage into the CRE.

These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

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

f.

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-27 (developmental)

HI 5.7.2.21 Battery Monitoring and Maintenance Program This Program provides controls for battery restoration and maintenance. The program shall be in accordance with IEEE Standard (Std) 450-2002, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," as endorsed by Regulatory Guide 1.129, Revision 2 (RG), with RG exceptions and program provisions as identified below:

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

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

2. RG 1.129, Regulatory Position 1, Subsection 2, "References,"

is not applicable to this program.

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

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

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

Procedures, Programs, and Manuals 5.7 5.7 Procedures, Programs, and Manuals (continued)

Watts Bar-Unit 2 5.0-28 (developmental)

HI 5.7.2.21 Battery Monitoring and Maintenance Program (continued)

b. The program shall include the following provisions:

1. Actions to restore battery cells with float voltage < 2.13 V;

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

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

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

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

SFDP 5.8 Watts Bar - Unit 2 5.0-29 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.8 Safety Function Determination Program (SFDP)

(moved to 5.7.2.18)

Reporting Requirements 5.9 (continued)

Watts Bar - Unit 2 5.0-30 (developmental)

H 5.0 ADMINISTRATIVE CONTROLS 5.9 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.9.1 DELETED 5.9.2 Annual Radiological Environmental Operating Report

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

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in the format of the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

Reporting Requirements 5.9 5.9 Reporting Requirements (continued)

(continued)

Watts Bar - Unit 2 5.0-31 (developmental)

B 5.9.3 Radioactive Effluent Release Report

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

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

The Radioactive Effluent Release Report covering the operation of the unit during the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

5.9.4 DELETED 5.9.5 CORE OPERATING LIMITS REPORT (COLR)

a.

Core operating limits shall be established prior to the initial and each reload cycle, or prior to any remaining portion of a cycle, and shall be documented in the COLR for the following:

LCO 3.1.4 Moderator Temperature Coefficient LCO 3.1.6 Shutdown Bank Insertion Limits LCO 3.1.7 Control Bank Insertion Limits LCO 3.2.1 Heat Flux Hot Channel Factor LCO 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor LCO 3.2.3 Axial Flux Difference LCO 3.9.1 Boron Concentration

b.

The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

Reporting Requirements 5.9 5.9 Reporting Requirements (continued)

(continued)

Watts Bar-Unit 2 5.0-32 (developmental)

B 5.9.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

1. WCAP-9272-P-A, WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY, July 1985 (W Proprietary). (Methodology for Specifications 3.1.4 - Moderator Temperature Coefficient, 3.1.6 -

Shutdown Bank Insertion Limit, 3.1.7 - Control Bank Insertion Limits, 3.2.1 - Heat Flux Hot Channel Factor, 3.2.2 - Nuclear Enthalpy Rise Hot Channel Factor, 3.2.3 - Axial Flux Difference, and 3.9.1 - Boron Concentration).

2a. WCAP-16009-P-A, Realistic Large-Break LOCA Evaluation Methodology Using the Automated Statistical Treatment of Uncertainty Method (ASTRUM), January 2005 (W Proprietary).(Methodology for Specification 3.2.1 - Heat Flux HotChannel Factor, and 3.2.2 - Nuclear Enthalpy Rise Hot Channel Factor).

2b. WCAP-10054-P-A, Small Break ECCS Evaluation Model Using NOTRUMP Code, August 1985. Addendum 2, Rev. 1: Addendum to the Westinghouse Small Break ECCS Evaluation Model using the NOTRUMP Code: Safety Injection into the Broken Loop and COSI Condensation Model, July 1997. (W Proprietary). (Methodology for Specifications 3.2.1 - Heat Flux Hot Channel Factor, and 3.2.2 - Nuclear Enthalpy Rise Hot Channel Factor).

3. WCAP-10216-P-A, Revision 1A, RELAXATION OF CONSTANT AXIAL OFFSET CONTROL F(Q) SURVEILLANCE TECHNICAL SPECIFICATION, February 1994 (W Proprietary). (Methodology for Specifications 3.2.1 - Heat Flux Hot Channel Factor (W(Z) Surveillance Requirements For F(Q) Methodology) and 3.2.3 - Axial Flux Difference (Relaxed Axial Offset Control).)

4. WCAP-12610-P-A, VANTAGE + FUEL ASSEMBLY REFERENCE CORE REPORT, April 1995. (W Proprietary). (Methodology for Specification 3.2.1 - Heat Flux Hot Channel Factor).

Reporting Requirements 5.9 5.9 Reporting Requirements (continued)

(continued)

Watts Bar-Unit 2 5.0-33 (developmental)

A 5.9.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

5. WCAP-15088-P, Rev. 1, Safety Evaluation Supporting A More Negative EOL Moderator Temperature Coefficient Technical Specification for the Watts Bar Nuclear Plant, July 1999, (W Proprietary), as approved by the NRC staffs Safety Evaluation accompanying the issuance of Amendment No. 20 (Methodology for Specification 3.1.4 - Moderator Temperature Coefficient.).

6. WCAP-11397-P-A, Revised Thermal Design Procedure, April 1989.

(Methodology for Specification 3.2.2 - Nuclear Enthalpy Rise Hot Channel Factor).

7. WCAP-15025-P-A, Modified WRB-2 Correlation, WRB-2M, for Predicting Critical Heat Flux in 17 x 17 Rod Bundles with Modified LPD Mixing Vane Grids, April 1999. (Methodology for Specification 3.2.2 - Nuclear Enthalpy Rise Hot Channel Factor).

8. WCAP-14565-P-A, VIPRE-01 Modeling and Qualification for Pressurized Water Reactor Non-LOCA Thermal-Hydraulic Safety Analysis, October 1999. (Methodology for Specification 3.2.2 - Nuclear Enthalpy Rise Hot Channel Factor).

c.

The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d.

The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

Reporting Requirements 5.9 5.9 Reporting Requirements (continued)

(continued)

Watts Bar-Unit 2 5.0-34 (developmental)

B 5.9.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a.

RCS pressure and temperature limits for heatup, cooldown, low temperature operation, criticality, and hydrostatic testing as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

LCO 3.4.3 RCS Pressure and Temperature (P/T) Limits

b.

The power operated relief valve lift settings required to support the Cold Overpressure Mitigation System (COMS) and the COMS arming temperature shall be established and documented in the PTLR for the following:

LCO 3.4.12 Cold Overpressure Mitigation System

c.

The analytical methods used to determine the RCS pressure and temperature limits and Cold Overpressure Mitigation System setpoints shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1.

WCAP-14040-A, Rev. 4 Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves.

2.

The PTLR will contain the complete identification for each of the TS reference Topical Reports used to prepare the PTLR (i.e., report number, title, revision, date, and any supplements).

d.

The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

Reporting Requirements 5.9 5.9 Reporting Requirements (continued)

Watts Bar-Unit 2 5.0-35 (developmental)

GI 5.9.7 EDG Failures Report If an individual emergency diesel generator (EDG) experiences four or more valid failures in the last 25 demands, these failures and any nonvalid failures experienced by that EDG in that time period shall be reported within 30 days.

Reports on EDG failures shall include the information recommended in Regulatory Guide 1.9, Revision 3, Regulatory Position C.4, or existing Regulatory Guide 1.108 reporting requirement.

5.9.8 PAMS Report When a Report is required by Condition B or F of LCO 3.3.3, Post Accident Monitoring (PAM) Instrumentation, a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.9.9 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.7.2.12, Steam Generator (SG) Program. The report shall include:

a.

The scope of inspections performed on each SG,

b.

Active dDegradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged or repaired during the inspection outage for each active degradation mechanism,

f.

The number and percentage of tubes plugged or repaired to date, and the effective plugging percentage in each steam generatorSG,

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing., and h.g. Repair method utilized and the number of tubes repaired by each repair method.

Record Retention 5.10 Watts Bar-Unit 2 5.0-36 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.10 Record Retention (removed from Technical Specifications)

High Radiation Area 5.11 (continued)

Watts Bar-Unit 2 5.0-37 (developmental)

A 5.0 ADMINISTRATIVE CONTROLS 5.11 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20:

5.11.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation

a.

Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.

b.

Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c.

Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d.

Each individual entering such an area shall possess:

1. A radiation monitoring device that continuously displays radiation dose rates in the area; or

2. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

3.

A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or

High Radiation Area 5.11 High Radiation Area (continued)

Watts Bar - Unit 2 5.0-38 (developmental)

A 5.11.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.

e.

Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

High Radiation Area 5.11 High Radiation Area (continued)

(continued)

Watts Bar - Unit 2 5.0-39 (developmental)

A 5.11.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation

a.

Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or, continuously guarded door or gate that prevents unauthorized entry, and, in addition:

1. All such door and gate keys shall be maintained under the administrative control of the Shift Manager, radiation protection manager, or his or her designee.

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

b.

Access to, and activities in, each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c.

Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d.

Each individual entering such an area shall possess:

1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

2.

A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or

High Radiation Area 5.11 High Radiation Area Watts Bar - Unit 2 5.0-40 (developmental)

B 5.11.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.

4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.

e.

Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

f.

Such individual areas that are within a larger area where no enclosure exists for the purpose of locking and where no enclosure can reasonably be constructed around the individual area need not be controlled by a locked door or gate, nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible flashing light shall be activated at the area as a warning device.

ML14170A045: Difference between revisions

Latest revision as of 20:19, 10 January 2025

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ML14170A045: Difference between revisions

Latest revision as of 20:19, 10 January 2025

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