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COL Appendix a, Tech Specs
	ML17088A314
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Site:	Turkey Point
Issue date:	04/12/2018
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	Hoellman J P/NRO/DNRL/LB4/301-415-5481
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APPENDIX A Turkey Point Unit 7 Technical Specifications

Technical Specifications TABLE OF CONTENTS Page 1.0 USE AND APPLICATION 1.1 Definitions.............................................................................................................. 1.1-1 1.2 Logical Connectors................................................................................................ 1.2-1 1.3 Completion Times.................................................................................................. 1.3-1 1.4 Frequency ............................................................................................................. 1.4-1 2.0 SAFETY LIMITS (SLs) 2.1 SLs ........................................................................................................................ 2.0-1 2.2 SL Violations.......................................................................................................... 2.0-1 3.0 LIMITING CONDITIONS FOR OPERATION (LCO) APPLICABILITY ......................... 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY .......................................... 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)...................................................................... 3.1.1-1 3.1.2 Core Reactivity ............................................................................................. 3.1.2-1 3.1.3 Moderator Temperature Coefficient (MTC) ................................................... 3.1.3-1 3.1.4 Rod Group Alignment Limits ......................................................................... 3.1.4-1 3.1.5 Shutdown Bank Insertion Limits ................................................................... 3.1.5-1 3.1.6 Control Bank Insertion Limits........................................................................ 3.1.6-1 3.1.7 Rod Position Indication ................................................................................. 3.1.7-1 3.1.8 PHYSICS TESTS Exceptions - MODE 2 ..................................................... 3.1.8-1 3.1.9 Chemical and Volume Control System (CVS) Demineralized Water Isolation Valves and Makeup Line Isolation Valves ...................... 3.1.9-1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (FQ(Z)) (FQ Methodology) ............................. 3.2.1-1 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor ( FNH ) ........................................ 3.2.2-1 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology) ............................................................... 3.2.3-1 3.2.4 QUADRANT POWER TILT RATIO (QPTR) .................................................. 3.2.4-1 3.2.5 OPDMS-Monitored Parameters.................................................................... 3.2.5-1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation ................................................. 3.3.1-1 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation ....................................................................................... 3.3.2-1 3.3.3 Post Accident Monitoring (PAM) Instrumentation ......................................... 3.3.3-1 3.3.4 Remote Shutdown Workstation (RSW) ........................................................ 3.3.4-1 3.3.5 Diverse Actuation System (DAS) Manual Controls....................................... 3.3.5-1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits ................................................................ 3.4.1-1 3.4.2 RCS Minimum Temperature for Criticality .................................................... 3.4.2-1 3.4.3 RCS Pressure and Temperature (P/T) Limits ............................................... 3.4.3-1 Turkey Point Unit 7 i

Technical Specifications TABLE OF CONTENTS Page 3.4 REACTOR COOLANT SYSTEM (continued) 3.4.4 RCS Loops ................................................................................................... 3.4.4-1 3.4.5 Pressurizer ................................................................................................... 3.4.5-1 3.4.6 Pressurizer Safety Valves............................................................................. 3.4.6-1 3.4.7 RCS Operational LEAKAGE......................................................................... 3.4.7-1 3.4.8 Minimum RCS Flow ...................................................................................... 3.4.8-1 3.4.9 RCS Leakage Detection Instrumentation ..................................................... 3.4.9-1 3.4.10 RCS Specific Activity .................................................................................. 3.4.10-1 3.4.11 Automatic Depressurization System (ADS) - Operating ............................ 3.4.11-1 3.4.12 Automatic Depressurization System (ADS) - Shutdown, RCS Intact ........ 3.4.12-1 3.4.13 Automatic Depressurization System (ADS) - Shutdown, RCS Open ........ 3.4.13-1 3.4.14 Low Temperature Overpressure Protection (LTOP) System ...................... 3.4.14-1 3.4.15 RCS Pressure Isolation Valve (PIV) Integrity ............................................. 3.4.15-1 3.4.16 Reactor Vessel Head Vent (RVHV) ............................................................ 3.4.16-1 3.4.17 Chemical and Volume Control System (CVS) Makeup Isolation Valves ................................................................................................... 3.4.17-1 3.4.18 Steam Generator (SG) Tube Integrity ......................................................... 3.4.18-1 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.1 Accumulators ................................................................................................ 3.5.1-1 3.5.2 Core Makeup Tanks (CMTs) - Operating ..................................................... 3.5.2-1 3.5.3 Core Makeup Tanks (CMTs) - Shutdown, RCS Intact .................................. 3.5.3-1 3.5.4 Passive Residual Heat Removal Heat Exchanger (PRHR HX) -

Operating ................................................................................................ 3.5.4-1 3.5.5 Passive Residual Heat Removal Heat Exchanger (PRHR HX) -

Shutdown, RCS Intact ............................................................................ 3.5.5-1 3.5.6 In-containment Refueling Water Storage Tank (IRWST) -

Operating ................................................................................................ 3.5.6-1 3.5.7 In-containment Refueling Water Storage Tank (IRWST) -

Shutdown, MODE 5 ................................................................................ 3.5.7-1 3.5.8 In-containment Refueling Water Storage Tank (IRWST) -

Shutdown, MODE 6 ................................................................................ 3.5.8-1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment ................................................................................................. 3.6.1-1 3.6.2 Containment Air Locks.................................................................................. 3.6.2-1 3.6.3 Containment Isolation Valves ....................................................................... 3.6.3-1 3.6.4 Containment Pressure .................................................................................. 3.6.4-1 3.6.5 Containment Air Temperature ....................................................................... 3.6.5-1 3.6.6 Passive Containment Cooling System (PCS) - Operating ........................... 3.6.6-1 3.6.7 Passive Containment Cooling System (PCS) - Shutdown ........................... 3.6.7-1 3.6.8 Containment Penetrations ............................................................................ 3.6.8-1 3.6.9 pH Adjustment .............................................................................................. 3.6.9-1 3.6.10 Vacuum Relief Valves ................................................................................ 3.6.10-1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) ............................................................ 3.7.1-1 Turkey Point Unit 7 ii

Technical Specifications TABLE OF CONTENTS Page 3.7 PLANT SYSTEMS (continued) 3.7.2 Main Steam Isolation Valves (MSIVs)........................................................... 3.7.2-1 3.7.3 Main Feedwater Isolation and Control Valves (MFIVs and MFCVs) ............ 3.7.3-1 3.7.4 Secondary Specific Activity ........................................................................... 3.7.4-1 3.7.5 Spent Fuel Pool Water Level ........................................................................ 3.7.5-1 3.7.6 Main Control Room Habitability System (VES) ............................................ 3.7.6-1 3.7.7 Startup Feedwater Isolation and Control Valves........................................... 3.7.7-1 3.7.8 Main Steam Line Leakage ............................................................................ 3.7.8-1 3.7.9 Fuel Storage Pool Makeup Water Sources .................................................. 3.7.9-1 3.7.10 Steam Generator Isolation Valves .............................................................. 3.7.10-1 3.7.11 Fuel Storage Pool Boron Concentration ..................................................... 3.7.11-1 3.7.12 Spent Fuel Pool Storage ............................................................................. 3.7.12-1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 DC Sources - Operating .............................................................................. 3.8.1-1 3.8.2 DC Sources - Shutdown .............................................................................. 3.8.2-1 3.8.3 Inverters - Operating .................................................................................... 3.8.3-1 3.8.4 Inverters - Shutdown.................................................................................... 3.8.4-1 3.8.5 Distribution Systems - Operating ................................................................. 3.8.5-1 3.8.6 Distribution Systems - Shutdown ................................................................. 3.8.6-1 3.8.7 Battery Parameters ...................................................................................... 3.8.7-1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration .................................................................................... 3.9.1-1 3.9.2 Unborated Water Source Flow Paths ........................................................... 3.9.2-1 3.9.3 Nuclear Instrumentation ............................................................................... 3.9.3-1 3.9.4 Refueling Cavity Water Level ....................................................................... 3.9.4-1 3.9.5 Containment Penetrations ............................................................................ 3.9.5-1 3.9.6 Containment Air Filtration System (VFS) ...................................................... 3.9.6-1 3.9.7 Decay Time .................................................................................................. 3.9.7-1 4.0 DESIGN FEATURES 4.1 Site ........................................................................................................................ 4.0-1 4.1.1 Site and Exclusion Boundaries ........................................................................ 4.0-1 4.1.2 Low Population Zone (LPZ) ............................................................................. 4.0-1 4.2 Reactor Core ......................................................................................................... 4.0-1 4.2.1 Fuel Assemblies .............................................................................................. 4.0-1 4.2.2 Control Rod and Gray Rod Assemblies ........................................................... 4.0-1 4.3 Fuel Storage .......................................................................................................... 4.0-2 4.3.1 Criticality .......................................................................................................... 4.0-2 4.3.2 Drainage .......................................................................................................... 4.0-3 4.3.3 Capacity........................................................................................................... 4.0-3 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility ........................................................................................................ 5.1-1 5.2 Organization .......................................................................................................... 5.2-1 5.3 Unit Staff Qualifications ......................................................................................... 5.3-1 Turkey Point Unit 7 iii

Technical Specifications TABLE OF CONTENTS Page 5.0 ADMINISTRATIVE CONTROLS (continued) 5.4 Procedures ............................................................................................................ 5.4-1 5.5 Programs and Manuals ......................................................................................... 5.5-1 5.6 Reporting Requirements ....................................................................................... 5.6-1 5.7 High Radiation Area .............................................................................................. 5.7-1 Turkey Point Unit 7 iv

Technical Specifications Definitions 1.1 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 DEVICE TEST An ACTUATION DEVICE TEST is a test of the actuated equipment. This test may consist of verification of actual operation but shall, at a minimum, consist of a continuity check of the associated actuated devices. The ACTUATION DEVICE TEST shall be conducted such that it provides component overlap with the ACTUATION LOGIC TEST.

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 shall be conducted such that it provides component overlap with the ACTUATION DEVICE TEST.

AXIAL FLUX DIFFERENCE AFD shall be the difference in normalized flux signals (AFD) 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 values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for OPERABILITY.

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 Turkey Point Unit 7 1.1 - 1

Technical Specifications Definitions 1.1 1.1 Definitions CHANNEL CALIBRATION (continued) devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps.

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 A COT shall be the injection of a simulated or actual signal TEST (COT) into the channel as close to the sensor as practicable to verify the OPERABILITY of all devices in the channel required for channel OPERABILITY. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints required for channel OPERABILITY such that the setpoints are within the necessary range and accuracy. The COT may be performed by means of any series of sequential, overlapping, or total channel steps.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or 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 The COLR is the unit specific document that provides cycle REPORT (COLR) specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these parameter 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 committed effective dose equivalent as the quantity and isotopic mixture of I-130, I-131, I-132, I-133, I-134, and I-135 actually present. The dose conversion factors used for this calculation shall be those listed in Table 2.1 of EPA Federal Guidance Report No. 11, Limiting Values of Radionuclide Turkey Point Unit 7 1.1 - 2

Technical Specifications Definitions 1.1 1.1 Definitions DOSE EQUIVALENT I-131 (continued)

Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion, EPA-520/

1-88-020, September 1988.

DOSE EQUIVALENT XE-133 DOSE EQUIVALENT XE-133 shall be that concentration of Xe-133 (microcuries per gram) that alone would produce the same effective dose equivalent as the quantity and isotopic mixture of noble gases (Kr-85m, Kr-85, Kr-87, Kr-88, Xe-131m, Xe-133m, Xe-133, Xe-135m, Xe-135, and Xe-138) actually present. The dose conversion factors used for this calculation shall be those listed in Table III.1 of EPA Federal Guidance Report No. 12, External Exposure to Radionuclides in Air, Water, and Soil, EPA 402-R-93-081, September 1993.

ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time interval from FEATURE (ESF) RESPONSE when the monitored parameter exceeds its actuation setpoint TIME at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions). 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 methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from seals or valve packing, 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; Turkey Point Unit 7 1.1 - 3

Technical Specifications Definitions 1.1 1.1 Definitions LEAKAGE (continued)

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

4. RCS LEAKAGE through the passive residual heat removal heat exchanger (PRHR HX) to the In-containment Refueling Water Storage Tank (IRWST).

b. Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE and PRHR HX tube LEAKAGE) through a nonisolatable fault in a RCS component body, pipe wall, or vessel wall.

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.

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).

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;

b. Authorized under the provisions of 10 CFR 50.59; or

c. Otherwise approved by the Nuclear Regulatory Commission.

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Technical Specifications Definitions 1.1 1.1 Definitions PRESSURE AND The PTLR is the unit specific document that provides the TEMPERATURE LIMITS reactor vessel pressure and temperature limits, including REPORT (PTLR) 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 5.6.6. Plant operation within these operating limits is addressed in LCO 3.4.3, RCS Pressure and Temperature (P/T) Limits and LCO 3.4.14, Low Temperature Overpressure Protection (LTOP) System.

QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper excore RATIO (QPTR) detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of 3400 MWt.

REACTOR TRIP CHANNEL A RTCOT shall be the injection of a simulated or actual signal OPERATIONAL TEST into the reactor trip channel as close to the sensor as (RTCOT) practicable to verify OPERABILITY of the required interlock and/or trip functions. The RTCOT may be performed by means of a series of sequential, overlapping, or total channel steps so that the entire channel is tested from the signal conditioner through the trip logic.

REACTOR TRIP SYSTEM The RTS RESPONSE TIME shall be that time interval from (RTS) RESPONSE TIME 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 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 assembly of highest reactivity worth, which is assumed to be fully withdrawn.

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Technical Specifications Definitions 1.1 1.1 Definitions SHUTDOWN MARGIN (continued)

However, with all RCCAs verified fully inserted by two independent means, it is not necessary to account for a stuck RCCA in the SDM calculation. With any RCCAs not capable of being fully inserted, the reactivity worth of these assemblies 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.

c. In MODE 2 with keff < 1.0, and MODES 3, 4, and 5, the worth of fully inserted Gray Rod Cluster Assemblies (GRCAs) will be included in the SDM calculation.

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 A TADOT shall consist of operating the trip actuating device OPERATIONAL TEST and verifying the OPERABILITY of all devices in the channel (TADOT) required for trip actuating device OPERABILITY. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy. The TADOT may be performed by means of any series of sequential, overlapping, or total channel steps.

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Technical Specifications Definitions 1.1 Table 1.1-1 (page 1 of 1)

MODES AVERAGE REACTIVITY % RATED REACTOR COOLANT CONDITION THERMAL TEMPERATURE MODES TITLE (keff) POWER(a) (°F) 1 Power Operation 0.99 >5 NA 2 Startup 0.99 5 NA 3 Hot Standby < 0.99 NA > 420 4 Safe Shutdown(b) < 0.99 NA 420 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.

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Technical Specifications Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in Technical Specifications are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meaning.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action).

The successive levels of logic are identified by additional digits of the Required Action number and by successive indentions of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

Turkey Point Unit 7 1.2 - 1

Technical Specifications Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)

EXAMPLE 1.2-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify . . .

AND A.2 Restore . . .

In this example, the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

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Technical Specifications Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)

EXAMPLE 1.2-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip ...

OR A.2.1 Verify ...

AND A.2.2.1 Reduce ...

OR A.2.2.2 Perform ...

OR A.3 Align ...

This example represents a more complicated use of logical connectors.

Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

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Technical Specifications Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.

Once a Condition has been entered, subsequent trains, subsystems, components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition, unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition.

However, when a subsequent train, subsystem, component, or variable, expressed in the Condition, is discovered to be inoperable or not within Turkey Point Unit 7 1.3 - 1

Technical Specifications Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued) limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:

a. Must exist concurrent with the first inoperability; and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.

The above Completion Time extension does not apply to a Completion Time with a modified time zero. This modified time zero may be expressed as a repetitive time (i.e., once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase from discovery .... Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in example 1.3-3 may not be extended.

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Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to be in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND in MODE 5 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months ) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months because the total time allowed for reaching MODE 5 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in MODE 3, the time allowed for reaching MODE 5 is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

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Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One valve A.1 Restore valve to 7 days inoperable. OPERABLE status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months When a valve is declared inoperable, Condition A is entered. If the valve is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion time clocks for Required Actions B.1 and B.2 start. If the inoperable valve is restored to OPERABLE status after Condition B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second valve is declared inoperable while the first valve is still inoperable, Condition A is not re-entered for the second valve. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable valve. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3, if one of the inoperable valves is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

While in LCO 3.0.3, if one of the inoperable valves is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

Turkey Point Unit 7 1.3 - 4

Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

On restoring one of the valves to OPERABLE status the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. This Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second valve being inoperable for > 7 days.

EXAMPLE 1.3-3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore Function X 7 days Function X train to OPERABLE train status. AND inoperable.

10 days from discovery of failure to meet the LCO B. One B.1 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y train to OPERABLE train status. AND inoperable.

10 days from discovery of failure to meet the LCO C. One C.1 Restore Function X 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function X train to OPERABLE train status.

inoperable.

OR AND C.2 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months One train to OPERABLE Function Y status.

train inoperable.

When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion Turkey Point Unit 7 1.3 - 5

Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was declared inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A).

The Completion Times of Conditions A and B are modified by a logical connector with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase from discovery of failure to meet the LCO is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal time zero for beginning the Completion Time clock. In this instance, the Completion Time time zero is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.

Turkey Point Unit 7 1.3 - 6

Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (including the extension) expires while one or more valves are still inoperable, Condition B is entered.

Turkey Point Unit 7 1.3 - 7

Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-5 ACTIONS

- NOTE -

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was only applicable to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve which caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve. Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

Turkey Point Unit 7 1.3 - 8

Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable.

OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to 50% RTP.

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

Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a once per Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2),

Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met, Condition B is entered.

If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.

Turkey Point Unit 7 1.3 - 9

Technical Specifications Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

EXAMPLE 1.3-7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem subsystem isolated.

inoperable. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter interval begins upon performance of Required Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

Turkey Point Unit 7 1.3 - 10

Technical Specifications Completion Times 1.3 1.3 Completion Times IMMEDIATE When Immediately is used as a Completion Time, the Required Action COMPLETION TIME should be pursued without delay and in a controlled manner.

Turkey Point Unit 7 1.3 - 11

Technical Specifications Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The specified Frequency is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR)

Applicability. The specified Frequency consists of the requirements of the Frequency column of each SR as well as certain Notes in the Surveillance column that modify performance requirements.

Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are otherwise stated conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillances, or both.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only required when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

The use of met or performed in these instances conveys specific meanings. A Surveillance is met only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not met. Performance refers only to the requirement to specifically determine the ability to meet the acceptance criteria.

Some Surveillances contain notes that modify the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be Turkey Point Unit 7 1.4 - 1

Technical Specifications Frequency 1.4 1.4 Frequency DESCRIPTION (continued) performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied:

a. The Surveillance is not required to be met in the MODE or other specified condition to be entered; or

b. The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or

c. The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed.

Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discusses these special situations.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

Turkey Point Unit 7 1.4 - 2

Technical Specifications Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated surveillance must be performed at least one time. Performance of the surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside the specified limits, or the Unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.

If the interval specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.

Turkey Point Unit 7 1.4 - 3

Technical Specifications Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector AND indicates that both Frequency requirements must be met. Each time the reactor power is increased from a power level

< 25% RTP to 25% RTP, the surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of Once indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by AND).

This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2. Thereafter indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the once performance in this example). If reactor power decreases to

< 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

Turkey Point Unit 7 1.4 - 4

Technical Specifications Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- NOTE -

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 25% RTP.

Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is < 25% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the specified Frequency. Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches 25% RTP to perform the Surveillance.

The Surveillance is still considered to be performed within the specified Frequency. Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was

< 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

Turkey Point Unit 7 1.4 - 5

Technical Specifications Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- NOTE -

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an otherwise stated exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2), but the unit was not in MODE 1, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

Turkey Point Unit 7 1.4 - 6

Technical Specifications Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- NOTE -

Only required to be performed in MODE 1.

Perform complete cycle of the valve. 7 days The interval continues, whether or not the unit operation is in MODE 1, 2, or 3 (the assumed Applicability of the associated LCO) between performances.

As the Note modifies the required performance of the Surveillance, the Note is construed to be part of the specified Frequency. Should the 7 day interval be exceeded while operation is not in MODE 1, this Note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the specified Frequency if completed prior to entering MODE 1.

Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was not in MODE 1, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not result in entry into MODE 1.

Once the unit reaches MODE 1, the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to entering MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

Turkey Point Unit 7 1.4 - 7

Technical Specifications Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- NOTE -

Not required to be met in MODE 3.

Verify parameter is within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in MODE 3 (the assumed Applicability of the associated LCO is MODES 1, 2, and 3). The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an otherwise stated exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2), and the unit was in MODE 3, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES to enter MODE 3, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change does not result in entry into MODE 2. Prior to entering MODE 2 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

Turkey Point Unit 7 1.4 - 8

Technical Specifications SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop cold leg temperature, and pressurizer pressure shall not exceed the limits specified in the COLR; and the following SLs shall not be exceeded:

2.1.1.1 The departure from nucleate boiling ratio (DNBR) shall be maintained 1.14 for the WRB-2M DNB correlation.

2.1.1.2 The peak fuel centerline temperature shall be maintained < 5080°F, decreasing by 58°F per 10,000 MWD/MTU of burnup.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5 the RCS pressure shall be maintained 2733.5 psig.

2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2.2 In MODE 3, 4, or 5, restore compliance within 5 minutes.

Turkey Point Unit 7 2.0 - 1

Technical Specifications LCO Applicability 3.0 3.0 LIMITING CONDITIONS FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and 3.0.6.

If the LCO is met, or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required, unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 3 within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ; and

b. MODE 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

c. MODE 5 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

Exceptions to this Specification are stated in the individual Specifications.

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

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4.

LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall not be made except when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time. This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or are part of a shutdown of the unit.

Exceptions to this Specification are stated in the individual Specifications.

LCO 3.0.4 is only applicable for entry into a MODE or other specified condition in the Applicability in MODES 1, 2, 3, and 4.

Turkey Point Unit 7 3.0 - 1

Technical Specifications LCO Applicability 3.0 3.0 LCO Applicability LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the test required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, additional evaluations and limitations may be required in accordance with Specification 5.5.7, Safety Function Determination Program (SFDP). 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.

When a support systems Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

LCO 3.0.7 Test Exception LCO 3.1.8 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Test Exception LCOs is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

LCO 3.0.8 When an LCO is not met and the associated ACTIONS are not met or an associated ACTION is not provided, action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to:

a. Restore inoperable equipment and

b. Monitor Safety System Shutdown Monitoring Trees parameters Exceptions to this Specification are stated in the individual Specifications.

Turkey Point Unit 7 3.0 - 2

Technical Specifications LCO Applicability 3.0 3.0 LCO Applicability LCO 3.0.8 (continued)

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.8 is not required.

LCO 3.0.8 is only applicable in MODES 5 and 6.

Turkey Point Unit 7 3.0 - 3

Technical Specifications SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified Conditions in the Applicability of individual LCOs, unless otherwise stated in the SR.

Failure to meet a Surveillance, whether such failure is experienced during the performance of the surveillance or between performances of the Surveillance, shall be a failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as once, the above interval extension does not apply.

If a Completion Time requires periodic performance on a once per...

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, which ever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

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

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

Turkey Point Unit 7 3.0 - 4

Technical Specifications SR Applicability 3.0 3.0 SR Applicability SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of a LCO shall not be made unless the LCOs Surveillances have been met within their specified Frequency. This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

SR 3.0.4 is only applicable for entry into a MODE or other specified condition in the Applicability in MODES 1, 2, 3, and 4.

Turkey Point Unit 7 3.0 - 5

Technical Specifications SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 The SDM shall be within the limits specified in the COLR.

APPLICABILITY: MODE 2 with keff < 1.0.

MODES 3, 4, and 5.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Turkey Point Unit 7 3.1.1 - 1

Technical Specifications Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within +/-1% k/k of the normalized predicted values.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Measured core A.1 Re-evaluate core design 7 days reactivity not within limit. and safety analysis, and determine that the reactor core is acceptable for continued operation.

AND A.2 Establish appropriate 7 days operating restrictions and SRs.

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

Turkey Point Unit 7 3.1.2 - 1

Technical Specifications Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 -----------------------------------------------------------------------

- NOTE -

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

Verify measured core reactivity is within +/-1% k/k of Prior to entering predicted values. MODE 1 after each refueling AND

- NOTE -

Only required after 60 EFPD 31 EFPD thereafter Turkey Point Unit 7 3.1.2 - 2

Technical Specifications MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR.

APPLICABILITY: MODE 1 for the upper MTC limit.

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 A.1 Establish administrative 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit. withdrawal limits for control banks to maintain MTC within limit.

B. Required Action and B.1 Be in MODE 2 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion keff < 1.0.

Time of Condition A not met.

C. MTC not within lower C.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC within upper limit. Prior to entering MODE 1 after each refueling Turkey Point Unit 7 3.1.3 - 1

Technical Specifications MTC 3.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.3.2 -----------------------------------------------------------------------

- NOTES -

1. 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.

2. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.

3. SR 3.1.3.2 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.

Verify MTC is within lower limit. Once each cycle Turkey Point Unit 7 3.1.3 - 2

Technical Specifications Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE.

AND Individual indicated rod positions shall be within 12 steps of their group step counter demand position.

- NOTE -

Not applicable to Gray Rod Cluster Assemblies (GRCAs) during GRCA bank sequence exchange with the On-Line Power Distribution Monitoring System (OPDMS) OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) A.1.1 Verify SDM to be within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. limits specified in the COLR.

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

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 B.1 Restore rod, to within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months with the alignment limits. alignment limits. OPDMS OPERABLE OR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with the OPDMS inoperable OR Turkey Point Unit 7 3.1.4 - 1

Technical Specifications Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2.1.1 Verify SDM to be within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limits specified in the COLR.

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

AND B.2.2 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to 75% RTP.

AND B.2.3 Verify SDM is within the Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limits specified in the COLR.

AND B.2.4 ------------------------------------

- NOTE -

Only required to be performed when OPDMS is inoperable.

Perform SR 3.2.1.1 and 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.2.1.2.

AND Turkey Point Unit 7 3.1.4 - 2

Technical Specifications Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2.5 ------------------------------------

- NOTE -

Only required to be performed when OPDMS is inoperable.

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 5 days analyses and confirm results remain valid for duration of operation under these conditions.

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

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

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

AND D.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Turkey Point Unit 7 3.1.4 - 3

Technical Specifications Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.1.4.2 -----------------------------------------------------------------------

- NOTE -

Not applicable to GRCAs.

Verify rod freedom of movement (trippability) by 92 days moving each rod not fully inserted in the core 10 steps in either direction.

SR 3.1.4.3 -----------------------------------------------------------------------

- NOTE -

Not applicable to GRCAs.

Verify rod drop time of each rod, from the fully Prior to reactor withdrawn position, is < 2.47 seconds from the criticality after beginning of decay of stationary gripper coil voltage to each removal of dashpot entry, with: the reactor head, and after each

a. Tavg 500°F, and earthquake requiring plant

b. All reactor coolant pumps operating. shutdown Turkey Point Unit 7 3.1.4 - 4

Technical Specifications Shutdown Bank Insertion Limits 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.5 Each Shutdown Bank shall be within insertion limits specified in the COLR.

APPLICABILITY: MODES 1 and 2.

- NOTE -

This LCO is not applicable while performing SR 3.1.4.2.

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

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

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

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

Turkey Point Unit 7 3.1.5 - 1

Technical Specifications Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the insertion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limits specified in the COLR.

Turkey Point Unit 7 3.1.5 - 2

Technical Specifications Control Bank Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Control Bank Insertion Limits LCO 3.1.6 Control banks shall be within the insertion, sequence, and overlap limits specified in the COLR.

APPLICABILITY: MODE 1.

MODE 2 with keff 1.0.

- NOTES -

1. This LCO is not applicable while performing SR 3.1.4.2.

2. This LCO is not applicable to Gray Rod Cluster Assembly (GRCA) banks during GRCA bank sequence exchange with OPDMS OPERABLE.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Control Bank insertion A.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limits not met. limits specified in the COLR.

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

AND A.2 Restore control bank(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within limits.

B. Control bank sequence B.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or overlap limits not limits specified in the met. COLR.

OR Turkey Point Unit 7 3.1.6 - 1

Technical Specifications Control Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND B.2 Restore control bank 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months sequence and overlap to within limits.

C. Required Action and C.1 Be in MODE 2 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion keff < 1.0.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify the estimated critical control bank position is Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within limits specified in the COLR. prior to achieving criticality SR 3.1.6.2 Verify each control bank insertion is within the limits 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months specified in the COLR.

SR 3.1.6.3 Verify sequence and overlap limits, specified in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COLR, are met for control banks not fully withdrawn from the core.

Turkey Point Unit 7 3.1.6 - 2

Technical Specifications Rod Position Indication 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication LCO 3.1.7 The Digital Rod Position Indication (DRPI) System and the Bank Demand Position Indication System shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

- NOTE -

Separate Condition entry is allowed for each inoperable rod position indicator and each demand position indicator.

CONDITION REQUIRED ACTION COMPLETION TIME A. One DRPI per group A.1 Verify the position of the Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for one or rods with inoperable more groups. position indicators by using the On-line Power Distribution Monitoring System (OPDMS).

OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to 50% RTP.

B. More than one DRPI B.1 Place the control rods Immediately per group inoperable. under manual control.

AND B.2 Monitor and record Once per 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Reactor Coolant System (RCS) Tavg.

AND Turkey Point Unit 7 3.1.7 - 1

Technical Specifications Rod Position Indication 3.1.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.3 Verify the position of the Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months rods with inoperable position indicators indirectly by using the incore detectors.

AND B.4 Restore inoperable 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months position indicators to OPERABLE status such that a maximum of one DRPI per group is inoperable.

C. One or more rods with C.1 Verify the position of the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable position rods with inoperable indicators have been position indicators by using moved in excess of the OPDMS.

24 steps in one direction since the last OR determination of the rods position. C.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to 50% RTP.

D. One demand position D.1.1 Verify by administrative Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months indicator per bank means all DRPIs for the inoperable for one or affected banks are more banks. OPERABLE.

AND D.1.2 Verify the most withdrawn Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months rod and the least withdrawn rod of the affected banks are 12 steps apart.

OR D.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to 50% RTP.

Turkey Point Unit 7 3.1.7 - 2

Technical Specifications Rod Position Indication 3.1.7 ACTIONS (continued)

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the group Prior to criticality demand position for the full indicated range of rod after each removal travel. of the reactor head Turkey Point Unit 7 3.1.7 - 3

Technical Specifications PHYSICS TESTS Exceptions

- MODE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PHYSICS TESTS Exceptions - MODE 2 LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of:

LCO 3.1.3 Moderator Temperature Coefficient (MTC),

LCO 3.1.4 Rod Group Alignment Limits, LCO 3.1.5 Shutdown Bank Insertion Limits, LCO 3.1.6 Control Bank Insertion Limits, and LCO 3.4.2 RCS Minimum Temperature for Criticality may be suspended, and the number of required channels for LCO 3.3.1, RTS Instrumentation, Functions 2, 3, 6, and 16.b, may be reduced to 3 provided:

a. Reactor Coolant System (RCS) lowest loop average temperature is 541°F,

b. SDM is within the limits specified in the COLR, and

c. THERMAL POWER is 5% RTP.

APPLICABILITY: During PHYSICS TESTS initiated in MODE 2.

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

AND A.2 Suspend PHYSICS TESTS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months exceptions.

B. THERMAL POWER not B.1 Open reactor trip breakers. Immediately within limit.

C. RCS lowest loop C.1 Restore RCS lowest loop 15 minutes average temperature average temperature to not within limit. within limit.

Turkey Point Unit 7 3.1.8 - 1

Technical Specifications PHYSICS TESTS Exceptions

- MODE 2 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 15 minutes Associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a REACTOR TRIP CHANNEL Prior to initiation of OPERATIONAL TEST on power range and PHYSICS TESTS intermediate range channels per SR 3.3.1.8 and SR 3.3.1.9.

SR 3.1.8.2 Verify the RCS lowest loop average temperature is 30 minutes 541°F.

SR 3.1.8.3 Verify THERMAL POWER is 5% RTP. 30 minutes SR 3.1.8.4 Verify SDM is within the limits specified in the COLR. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Turkey Point Unit 7 3.1.8 - 2

Technical Specifications CVS Demineralized Water Isolation Valves and Makeup Line Isolation Valves 3.1.9 3.1 REACTIVITY CONTROL SYSTEMS 3.1.9 Chemical and Volume Control System (CVS) Demineralized Water Isolation Valves and Makeup Line Isolation Valves LCO 3.1.9 Two CVS Demineralized Water Isolation Valves and two Makeup Line Isolation Valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CVS demineralized A.1 Restore two CVS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months water isolation valve demineralized water inoperable. isolation valves and two makeup line isolation OR valves to OPERABLE status.

One makeup line isolation valve inoperable.

OR One CVS demineralized water isolation valve and one makeup line isolation valve inoperable.

Turkey Point Unit 7 3.1.9 - 1

Technical Specifications CVS Demineralized Water Isolation Valves and Makeup Line Isolation Valves 3.1.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 ------------------------------------

associated Completion - NOTE -

Time of Condition not Flow path(s) may be met. unisolated intermittently under administrative OR controls.

Two CVS demineralized water isolation valves Isolate the flow path from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. the demineralized water storage tank to the Reactor OR Coolant System by use of at least one closed manual Two makeup line or one closed and isolation valves de-activated automatic inoperable. valve.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Verify two CVS demineralized water isolation valves In accordance with and two makeup line isolation valves are OPERABLE the Inservice by stroking the valve closed. Testing Program Turkey Point Unit 7 3.1.9 - 2

Technical Specifications FQ(Z) (FQ Methodology) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (FQ(Z)) (FQ Methodology)

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

APPLICABILITY: MODE 1 with On-line Power Distribution Monitoring System (OPDMS) inoperable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------------------------------- A.1 Reduce THERMAL 15 minutes after each

- NOTE - POWER 1% RTP for FQC ( Z) determination Required Action A.4 each 1% FQC ( Z) exceeds shall be completed limit.

whenever this Condition is entered. AND A.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each FQC ( Z) not within limit. Neutron Flux - High trip FQC ( Z) determination setpoints 1% for each 1% FQC ( Z) exceeds limit.

AND A.3 Reduce Overpower T trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each setpoints 1% for each FQC ( Z) determination 1% FQC ( Z) exceeds limit.

AND A.4 Perform SR 3.2.1.1 and Prior to increasing SR 3.2.1.2. THERMAL POWER above the limit of Required Action A.1 Turkey Point Unit 7 3.2.1 - 1

Technical Specifications FQ(Z) (FQ Methodology) 3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. -------------------------------- B.1 Reduce AFD limits 1% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

- NOTE - for each 1% FQW ( Z)

Required Action B.4 exceeds limit.

shall be completed whenever this Condition AND is entered.

B.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Neutron Flux - High trip FQW ( Z) not within limits. setpoints 1% for each 1% that the maximum allowable power of the AFD limits is reduced.

AND B.3 Reduce Overpower T trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months setpoints 1% for each 1% that the maximum allowable power of the AFD limits is reduced.

AND B.4 Perform SR 3.2.1.1 and Prior to increasing SR 3.2.1.2. THERMAL POWER above the maximum allowable power of the AFD limits C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Turkey Point Unit 7 3.2.1 - 2

Technical Specifications FQ(Z) (FQ Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS

- NOTES -

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

2. If the OPDMS becomes inoperable while in MODE 1 these surveillances must be performed within 31 days of the last verification of OPDMS parameters.

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify FQC ( Z) within limit. Once after 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 FQC ( Z) was last verified AND 31 effective full power days (EFPD) thereafter Turkey Point Unit 7 3.2.1 - 3

Technical Specifications FQ(Z) (FQ Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.1.2 -----------------------------------------------------------------------

- NOTE -

If FQW ( Z) measurements indicate maximum over z FQC ( Z ) has increased since the previous evaluation of FQC ( Z ) :

a. Increase FQW ( Z) by the greater of a factor of 1.02 or by an appropriate factor specified in the COLR and reverify FQW ( Z) is within limits; or

b. Repeat SR 3.2.1.2 once per 7 EFPD until two successive flux maps indicate maximum over z FQC ( Z ) has not increased.

Verify FQW ( Z) within limits. Once after 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 FQW ( Z) was last verified AND 31 EFPD thereafter Turkey Point Unit 7 3.2.1 - 4

Technical Specifications FNH 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor ( FNH )

LCO 3.2.2 FNH shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1 with On-line Power Distribution Monitoring System (OPDMS) inoperable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------------------------------- A.1.1 Restore FNH to within limit. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

- NOTE -

Required Actions A.2 OR and A.3 must be completed whenever A.1.2.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Condition A is entered. POWER to < 50% RTP.

AND FNH not within limits.

A.1.2.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Neutron Flux - High trip setpoints to 55% RTP.

AND A.2 Perform SR 3.2.2.1. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND Turkey Point Unit 7 3.2.2 - 1

Technical Specifications FNH 3.2.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.3 ------------------------------------

- NOTE -

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

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER reaching 95% RTP B. Required Action B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time not met.

Turkey Point Unit 7 3.2.2 - 2

Technical Specifications FNH 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 -----------------------------------------------------------------------

- NOTE -

If the OPDMS becomes inoperable while in MODE 1 these Surveillances must be performed within 31 days of the last verification of OPDMS parameters.

Verify FNH within limits specified in the COLR. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND 31 effective full power days (EFPD) thereafter Turkey Point Unit 7 3.2.2 - 3

Technical Specifications AFD (RAOC Methodology) 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology)

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 and with the On-Line Power Distribution Monitoring System (OPDMS) inoperable.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore 7 days channel.

Turkey Point Unit 7 3.2.3 - 1

Technical Specifications QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be 1.02.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP and with the On-Line Power Distribution Monitoring System (OPDMS) inoperable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. QPTR not within limit. A.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after each POWER 3% from RTP QPTR determination for each 1% of QPTR

> 1.00.

AND A.2 Perform SR 3.2.4.1. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND A.3 Perform SR 3.2.1.1 and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.2.1. achieving equilibrium conditions from a THERMAL POWER reduction per Required Action A.1 AND Once per 7 days thereafter AND A.4 Reevaluate safety Prior to increasing analyses and confirm THERMAL POWER results remain valid for above the limit of duration of operation under Required Action A.1 this condition.

AND Turkey Point Unit 7 3.2.4 - 1

Technical Specifications QPTR 3.2.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.5 ------------------------------------

- NOTES -

1. Perform Required Action A.5 only after Required Action A.4 is completed.

2. Required Action A.6 shall be completed whenever Required Action A.5 is performed.

Normalize excore Prior to increasing detectors to restore QPTR THERMAL POWER to within limit. above the limit of Required Action A.1 AND A.6 ------------------------------------

- NOTE -

Perform Required Action A.6 only after Required Action A.5 is completed.

Perform SR 3.2.1.1, Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.1.2, and achieving equilibrium SR 3.2.2.1. conditions at RTP not to exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and associated POWER to 50% RTP.

Completion Time not met.

Turkey Point Unit 7 3.2.4 - 2

Technical Specifications QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 -----------------------------------------------------------------------

- NOTES -

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

2. SR 3.2.4.2 may be performed in lieu of this Surveillance.

Verify QPTR within limit by calculation. 7 days SR 3.2.4.2 -----------------------------------------------------------------------

- NOTE -

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER 75% RTP.

Verify QPTR is within limit using a minimum of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 4 symmetric pairs of fixed incore detectors.

Turkey Point Unit 7 3.2.4 - 3

Technical Specifications OPDMS-Monitored Parameters 3.2.5 3.2 POWER DISTRIBUTION LIMITS 3.2.5 On-Line Power Distribution Monitoring System (OPDMS)-Monitored Parameters LCO 3.2.5 The following parameters shall not exceed their operating limits as specified in the COLR:

a. Peak kw/ft(Z)

b. FNH

c. DNBR

d. SDM.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP with OPDMS OPERABLE for parameters a, b, and c.

MODE 1 with OPDMS OPERABLE for parameter d.

2 with keff 1.0 and OPDMS OPERABLE for parameter d.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Restore all parameters to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months parameters a. through within limits.

c. above not within limits.

B. Required Action B.1 ------------------------------------

and associated - NOTE -

Completion Time of If the power distribution Condition A not met. parameters are restored to within their limits while power is being reduced, operation may continue at the power level where this occurs.

Reduce THERMAL POWER to 50% RTP. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months C. Parameter d above not C.1 Initiate boration to restore 15 minutes within limits. SDM to within limits.

Turkey Point Unit 7 3.2.5 - 1

Technical Specifications OPDMS-Monitored Parameters 3.2.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.5.1 Verify the parameters a. through d. to be within their 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months with limits. OPDMS alarms OPERABLE OR 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with OPDMS alarms inoperable Turkey Point Unit 7 3.2.5 - 2

Technical Specifications RTS Instrumentation 3.3.1 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 A.1 Enter the Condition Immediately with one or more referenced in Table 3.3.1-1 required channels for the channel(s).

inoperable.

B. One manual initiation B.1 Restore manual initiation 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months device inoperable. device to OPERABLE status.

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

C. One manual initiation C.1 Restore manual initiation 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months device inoperable. device to OPERABLE status.

OR C.2 Open RTBs. 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months Turkey Point Unit 7 3.3.1 - 1

Technical Specifications RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or two Power D.1.1 Reduce THERMAL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Range Neutron Flux - POWER to 75% RTP.

High channels inoperable. AND D.1.2 Place one inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months channel in bypass or trip.

AND D.1.3 With two inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months channels, place one channel in bypass and one channel in trip.

OR D.2.1 Place inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months channel(s) in bypass.

AND D.2.2 ------------------------------------

- NOTE -

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

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. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.3.1 - 2

Technical Specifications RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or two channels E.1.1 Place one inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable. channel in bypass or trip.

AND E.1.2 With two channels 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable, place one channel in bypass and one channel in trip.

OR E.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. THERMAL POWER F.1.1 Place one inoperable 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months between P-6 and P-10, channel in bypass or trip.

one or two Intermediate Range Neutron Flux AND channels inoperable.

F.1.2 With two channels 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable, place one channel in bypass and one channel in trip.

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

OR F.3 Increase THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to > P-10.

G. THERMAL POWER G.1 Suspend operations Immediately between P-6 and P-10, involving positive reactivity three Intermediate additions.

Range Neutron Flux channels inoperable. AND G.2 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to < P-6.

Turkey Point Unit 7 3.3.1 - 3

Technical Specifications RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. THERMAL POWER H.1 Restore three of four Prior to increasing

< P-6, one or two channels to OPERABLE THERMAL POWER to Intermediate Range status. > P-6 Neutron Flux channels inoperable.

I. One or two Source I.1 Suspend operations Immediately Range Neutron Flux involving positive reactivity channels inoperable. additions.

J. Three Source Range J.1 Open RTBs. Immediately Neutron Flux channels inoperable.

K. One or two channels K.1.1 Place one inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable. channel in bypass or trip.

AND K.1.2 With two channels 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable, place one channel in bypass and one channel in trip.

OR K.2 Reduce THERMAL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months POWER to < P-10.

L. One or two channels/ L.1 Restore three of four 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months divisions inoperable. channels/divisions to OPERABLE status.

OR L.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.3.1 - 4

Technical Specifications RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME M. One or two interlock M.1 Verify the interlocks are in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months channels inoperable. required state for existing plant conditions.

OR M.2.1 Place the Functions 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months associated with one inoperable interlock channel in bypass or trip.

AND M.2.2 With two interlock 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months channels inoperable, place the Functions associated with one inoperable interlock channel in bypass and with one inoperable interlock channel in trip.

OR M.3 Be in MODE 3. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months N. One division inoperable. N.1 Open RTBs in inoperable 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months division.

OR N.2.1 Be in MODE 3, 4, or 5. 14 hours1.62037e-4 days 0.00389 hours 2.314815e-5 weeks 5.327e-6 months AND N.2.2 Open RTBs. 14 hours1.62037e-4 days 0.00389 hours 2.314815e-5 weeks 5.327e-6 months Turkey Point Unit 7 3.3.1 - 5

Technical Specifications RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME O. Two divisions O.1 Restore three of four 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. divisions to OPERABLE status.

OR O.2.1 Be in MODE 3, 4, or 5. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND O.2.2 Open RTBs. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months P. One or two channels/ P.1 Restore three of four 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months divisions inoperable. channels/divisions to OPERABLE status.

OR P.2 Open RTBs. 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months Q. One or two Source Q.1 Restore three of four 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Range Neutron Flux channels to OPERABLE channel inoperable. status.

OR Q.2 Open RTBs. 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months R. Required Source Range R.1 Suspend operations Immediately Neutron Flux channel involving positive reactivity inoperable. additions.

AND R.2 Close unborated water 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months source isolation valves.

AND R.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 Turkey Point Unit 7 3.3.1 - 6

Technical Specifications RTS Instrumentation 3.3.1 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 nuclear instrument channel in the Protection and Safety Monitoring System (PMS) if absolute difference is > 1% RTP.

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

3. If the calorimetric heat balance is < 70% RTP, and if the nuclear instrumentation channel indicated power is:

a. lower than the calorimetric measurement by

> 1%, then adjust the nuclear instrumentation channel upward to match the calorimetric measurement.

b. higher than the calorimetric measurement, then no adjustment is required.

Compare results of calorimetric heat balance to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months nuclear instrument channel output.

Turkey Point Unit 7 3.3.1 - 7

Technical Specifications RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

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

- NOTES -

1. Adjust the conversion factor, T°, in the T power calculation (qT) if absolute difference between qT and the calorimetric measurement is > 1% RTP.

2. Required to be met within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching 50% RTP.

3. If the calorimetric heat balance is < 70% RTP, and if qT is:

a. lower than the calorimetric measurement by > 5%, then adjust T° to match the calorimetric measurement.

b. higher than the calorimetric measurement, then no adjustment is required.

Compare results of calorimetric heat balance to the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months T power calculation (qT) output.

SR 3.3.1.4 -----------------------------------------------------------------------

- NOTES -

1. Adjust nuclear instrument channel in PMS if absolute difference is 3% AFD.

2. Required to be met within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching 20% RTP.

Compare results of the incore detector measurements 31 effective full to nuclear instrument channel AXIAL FLUX power days DIFFERENCE. (EFPD)

Turkey Point Unit 7 3.3.1 - 8

Technical Specifications RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.5 -----------------------------------------------------------------------

- NOTE -

Required to be met within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching 50% RTP.

Calibrate excore channels to agree with incore 92 EFPD detector measurements.

SR 3.3.1.6 -----------------------------------------------------------------------

- NOTE -

This Surveillance must be performed on both reactor trip breakers associated with a single division.

Perform TADOT. 92 days on a STAGGERED TEST BASIS SR 3.3.1.7 Perform RTCOT. 92 days SR 3.3.1.8 -----------------------------------------------------------------------

- NOTE -

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.

Perform RTCOT in accordance with Setpoint 92 days Program.

Turkey Point Unit 7 3.3.1 - 9

Technical Specifications RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

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

- NOTE - - NOTE -

This Surveillance shall include verification that Only required interlocks P-6 and P-10 are in their required state for when not existing unit conditions. performed within

previous 92 days Perform RTCOT in accordance with Setpoint Program. Prior to reactor startup AND Four hours after reducing power below P-10 for power and intermediate instrumentation AND Four hours after reducing power below P-6 for source range instrumentation AND Every 92 days thereafter SR 3.3.1.10 -----------------------------------------------------------------------

- NOTE -

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

Perform CHANNEL CALIBRATION in accordance 24 months with Setpoint Program.

Turkey Point Unit 7 3.3.1 - 10

Technical Specifications RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.11 -----------------------------------------------------------------------

- NOTE -

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION in accordance 24 months with Setpoint Program.

SR 3.3.1.12 -----------------------------------------------------------------------

- NOTE -

Verification of setpoint is not required.

Perform TADOT. 24 months SR 3.3.1.13 -----------------------------------------------------------------------

- NOTE -

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits. 24 months on a STAGGERED TEST BASIS Turkey Point Unit 7 3.3.1 - 11

Technical Specifications RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 4)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

1. Manual Reactor Trip 1,2 2 B SR 3.3.1.12 3(a),4(a),5(a) 2 C SR 3.3.1.12

2. Power Range Neutron Flux

a. High Setpoint 1,2 4 D SR 3.3.1.1 SR 3.3.1.2 SR 3.3.1.8 SR 3.3.1.11 SR 3.3.1.13

b. Low Setpoint 1(b),2 4 E SR 3.3.1.1 SR 3.3.1.9 SR 3.3.1.11 SR 3.3.1.13

3. Power Range Neutron Flux High 1,2 4 E SR 3.3.1.8 Positive Rate SR 3.3.1.11 SR 3.3.1.13

4. Intermediate Range Neutron Flux 1(b),2(c) 4 F,G SR 3.3.1.1 SR 3.3.1.9 SR 3.3.1.11 SR 3.3.1.13 2(d) 4 H SR 3.3.1.1 SR 3.3.1.9 SR 3.3.1.11 SR 3.3.1.13

5. Source Range Neutron Flux High 2(d) 4 I,J SR 3.3.1.1 Setpoint SR 3.3.1.9 SR 3.3.1.11 SR 3.3.1.13 3(a),4(a),5(a) 4 J,Q SR 3.3.1.1 SR 3.3.1.8 SR 3.3.1.11 SR 3.3.1.13 3(e),4(e),5(e) 1 R SR 3.3.1.1 SR 3.3.1.11 (a) With Reactor Trip Breakers (RTBs) closed and Plant Control System capable of rod withdrawal.

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

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

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

(e) With RTBs open. In this condition, Source Range Function does not provide reactor trip but does provide indication.

Turkey Point Unit 7 3.3.1 - 12

Technical Specifications RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 4)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

6. Overtemperature T 1,2 4 (2/loop) E SR 3.3.1.1 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

7. Overpower T 1,2 4 (2/loop) E SR 3.3.1.1 SR 3.3.1.3 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

8. Pressurizer Pressure 1(f) 4 K SR 3.3.1.1 SR 3.3.1.8

a. Low Setpoint SR 3.3.1.10 SR 3.3.1.13

b. High Setpoint 1,2 4 E SR 3.3.1.1 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

9. Pressurizer Water Level - High 3 1(f) 4 K SR 3.3.1.1 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

10. Reactor Coolant Flow - Low 1(f) 4 per hot leg K SR 3.3.1.1 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

11. Reactor Coolant Pump (RCP) 1,2 4 per RCP E SR 3.3.1.1 Bearing Water Temperature - SR 3.3.1.8 High SR 3.3.1.10 SR 3.3.1.13

12. RCP Speed - Low 1(f) 4 (1/pump) K SR 3.3.1.1 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

13. Steam Generator (SG) Narrow 1,2 4 per SG E SR 3.3.1.1 Range Water Level - Low SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13 (f) Above the P-10 (Power Range Neutron Flux) interlock.

Turkey Point Unit 7 3.3.1 - 13

Technical Specifications RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 3 of 4)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

14. Steam Generator (SG) Narrow 1,2(g) 4 per SG E SR 3.3.1.1 Range Water Level - High 2 SR 3.3.1.8 SR 3.3.1.10 SR 3.3.1.13

15. Safeguards Actuation Input from Engineered Safety Feature Actuation System

a. Manual 1,2 2 B SR 3.3.1.12

b. Automatic 1,2 4 L SR 3.3.1.7

16. Reactor Trip System Interlocks

a. Intermediate Range Neutron 2 4 M SR 3.3.1.8 Flux, P-6 SR 3.3.1.11

b. Power Range Neutron Flux, 1,2 4 M SR 3.3.1.8 P-10 SR 3.3.1.11

c. Pressurizer Pressure, P-11 1,2 4 M SR 3.3.1.8 SR 3.3.1.11

17. Reactor Trip Breakers 1,2,3(a),4(a),5(a) 4 divisions with 2 N,O SR 3.3.1.6 RTBs per division

18. Reactor Trip Breaker (RTB) 1,2,3(a),4(a),5(a) 1 each per RTB N,O SR 3.3.1.6 Undervoltage and Shunt Trip mechanism Mechanisms

19. Automatic Trip Logic 1,2 4 divisions L SR 3.3.1.7 3(a),4(a),5(a) 4 divisions P SR 3.3.1.7

20. ADS Stages 1, 2, and 3 Actuation input from engineered safety feature actuation system

a. Manual 1,2,3(a),4(a),5(a) 2 switch sets B SR 3.3.1.12

b. Automatic 1,2 4 L SR 3.3.1.7 3(a),4(a),5(a) 4 P SR 3.3.1.7 (a) With Reactor Trip Breakers closed and Plant Control System capable of rod withdrawal.

(g) Above the P-11 (Pressurizer Pressure) interlock.

Turkey Point Unit 7 3.3.1 - 14

Technical Specifications RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 4)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

21. Core Makeup Tank Actuation input from engineered safety feature actuation system

a. Manual 1,2,3(a),4(a),5(a) 2 switch sets B SR 3.3.1.12

b. Automatic 1,2 4 L SR 3.3.1.7 3(a),4(a),5(a) 4 P SR 3.3.1.7

22. Passive Residual Heat Removal 1,2 4 per valve E SR 3.3.1.11 Actuation SR 3.3.1.12 SR 3.3.1.13 (a) With Reactor Trip Breakers (RTBs) closed and Plant Control System capable of rod withdrawal.

Turkey Point Unit 7 3.3.1 - 15

Technical Specifications ESFAS Instrumentation 3.3.2 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

- NOTES -

1. Separate condition entry is allowed for each Function.

2. The Conditions for each Function are given in Table 3.3.2-1. If the Required Actions and associated Completion Times of the first Condition are not met, refer to the second Condition.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more referenced in Table 3.3.2-1 required channels or for the channel(s) or divisions inoperable. division(s).

B. One or two channels or B.1 Place one inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months divisions inoperable. channel or division in bypass or trip.

AND B.2 With two inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months channels or divisions, place one inoperable channel or division in bypass and one inoperable channel or division in trip.

C. One channel C.1 Place inoperable channel 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable. in bypass.

Turkey Point Unit 7 3.3.2 - 1

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One required division D.1 Restore required division 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable. to OPERABLE status.

E. One switch or switch set E.1 Restore switch and switch 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. set to OPERABLE status.

F. One channel F.1 Restore channel to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

OR F.2.1 Verify alternate radiation 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months monitors are OPERABLE.

AND F.2.2 Verify main control room 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months isolation, air supply initiation and electrical load de-energization manual controls are OPERABLE.

G. One switch, switch set, G.1 Restore switch, switch set, 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channel, or division channel, and division to inoperable. OPERABLE status.

H. One channel H.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable.

I. One or two channels I.1 Place one inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable. channel in bypass or trip.

AND I.2 With two inoperable 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months channels, place one channel in bypass and one channel in trip.

J. One or two interlock J.1 Verify the interlocks are in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months channels inoperable. the required state for the existing plant conditions.

OR Turkey Point Unit 7 3.3.2 - 2

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J.2.1 Place the Functions 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months associated with one inoperable interlock channel in bypass or trip.

AND J.2.2 With two interlock 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months channels inoperable, place the Functions associated with one inoperable interlock channel in bypass and with one inoperable interlock channel in trip.

K. Required Action K.1 ------------------------------------

and associated - NOTE -

Completion Time LCO 3.0.8 is not not met. applicable.

Suspend movement of Immediately irradiated fuel assemblies.

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

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

M.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months N. Required Action N.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time AND not met.

N.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Reactor Coolant System (RCS) cooling provided by the Normal Residual Heat Removal System (RNS).

Turkey Point Unit 7 3.3.2 - 3

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

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

O.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months P. Required Action ---------------------------------------------

and associated - NOTE -

Completion Time Flow path(s) may be unisolated not met. intermittently under administrative controls.

P.1 Isolate the affected flow 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months path(s).

AND P.2.1 Isolate the affected flow 7 days path(s) by use of at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

OR P.2.2 Verify the affected flow Once per 7 days path is isolated.

Q. Required Action Q.1 ------------------------------------

and associated - NOTE -

Completion Time Flow path(s) may be not met. unisolated intermittently under administrative controls.

Turkey Point Unit 7 3.3.2 - 4

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Isolate the affected flow 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months path(s) by use of at least one closed manual or closed and de-activated automatic valve.

OR Q.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND Q.2.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months R. Required Action R.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time AND not met.

- NOTE -

Flow path(s) may be unisolated intermittently under administrative controls.

R.2.1.1 Isolate the affected flow 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months path(s).

AND R.2.1.2 Verify the affected flow Once per 7 days path is isolated.

OR R.2.2 Be in MODE 4 with the 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months RCS cooling provided by the RNS.

Turkey Point Unit 7 3.3.2 - 5

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

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

S.2.1.1 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RCS cooling provided by the RNS.

AND

- NOTE -

Flow path(s) may be unisolated intermittently under administrative controls.

S.2.1.2 Isolate the affected flow 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months path(s).

AND S.2.1.3 Verify the affected flow Once per 7 days path is isolated.

OR S.2.2 Be in MODE 5. 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months T. Required Action ---------------------------------------------

and associated - NOTE -

Completion Time Flow path(s) may be unisolated not met. intermittently under administrative controls.

T.1.1 Isolate the affected flow 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months path(s).

AND Turkey Point Unit 7 3.3.2 - 6

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME T.1.2.1 Isolate the affected flow 7 days path(s) by use of at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

OR T.1.2.2 Verify the affected flow Once per 7 days path is isolated.

OR T.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND T.2.2 Be in MODE 5. 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months U. Required Action U.1 Be in MODE 5. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and associated Completion Time AND not met.

U.2 Initiate action to open the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RCS pressure boundary and establish a pressurizer level 20%.

V. Required Action V.1 Restore the inoperable 168 hours0.00194 days 0.0467 hours 2.777778e-4 weeks 6.3924e-5 months and associated channel(s).

Completion Time not met. OR V.2.1 Be in MODE 5. 180 hours0.00208 days 0.05 hours 2.97619e-4 weeks 6.849e-5 months AND V.2.2 Initiate action to open the 180 hours0.00208 days 0.05 hours 2.97619e-4 weeks 6.849e-5 months RCS pressure boundary and establish a pressurizer level 20%.

Turkey Point Unit 7 3.3.2 - 7

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME W. Required Action W.1 If in MODE 5 with the RCS Immediately and associated open and < 20%

Completion Time pressurizer level, initiate not met. action to be MODE 5 with the RCS pressure boundary open and 20% pressurizer level.

AND W.2 If in MODE 5, isolate the Immediately flow path from the demineralized water storage tank to the RCS by use of at least one closed and de-activated automatic valve or closed manual valve.

AND W.3 If in MODE 6, initiate Immediately action to be in MODE 6 with the water level 23 feet above the top of the reactor vessel flange.

AND W.4 Suspend positive reactivity Immediately additions.

X. Required Action X.1 If in MODE 5 with RCS Immediately and associated open and < 20%

Completion Time pressurizer level, initiate not met. action to be in MODE 5 with RCS open and 20%

pressurizer level.

AND Turkey Point Unit 7 3.3.2 - 8

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME X.2 If in MODE 6 with upper Immediately internals in place, initiate action to be in MODE 6 with the upper internals removed.

AND X.3 Suspend positive reactivity Immediately additions.

Y. Required Action Y.1 Suspend positive reactivity Immediately and associated additions.

Completion Time not met. AND Y.2 If in MODE 4, be in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months MODE 5.

AND Y.3 If in MODE 4 or 5, initiate 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months action to establish a pressurizer level > 20%

with the RCS pressure boundary intact.

AND Y.4 If in MODE 6, initiate Immediately action to be in MODE 6 with the water level

> 23 feet above the top of the reactor vessel flange.

Z. Required Action Z.1 ------------------------------------

and associated - NOTE -

Completion Time Flow path(s) may be not met. unisolated intermittently under administrative controls.

Turkey Point Unit 7 3.3.2 - 9

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Isolate the affected flow 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months path(s) by use of at least one closed manual or closed and deactivated automatic valve.

OR Z.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND Z.2.2 Be in MODE 4 with the 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months RCS cooling provided by the RNS.

AA. Required Action ---------------------------------------------

and associated - NOTE -

Completion Time Flow path(s) may be unisolated not met. intermittently under administrative controls.

AA.1.1 Isolate the affected flow 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months path(s).

AND AA.1.2.1 Isolate the affected flow 7 days path(s) by use of at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

OR Turkey Point Unit 7 3.3.2 - 10

Technical Specifications ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME AA.1.2.2 Verify the affected flow Once per 7 days path is isolated.

OR AA.2.1 If in MODE 4, be in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months MODE 5.

AND AA.2.2 If in MODE 4 or 5, initiate 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months action to establish a pressurizer level 20%.

AND AA.2.3 If in MODE 6, initiate Immediately action to be in MODE 6 with the water level 23 feet above the top of the reactor vessel flange.

BB. One channel BB.1 Place channel in bypass. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable.

AND BB.2 Continuously monitor hot 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months leg level.

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

AND CC.2 Be in MODE 5 or 6. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months AND CC.3 Open a containment air 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months flow path 6 inches in diameter.

Turkey Point Unit 7 3.3.2 - 11

Technical Specifications ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS

- NOTE -

Refer to Table 3.3.2-1 to determine which SRs apply for each Engineered Safety Features (ESF) 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 -----------------------------------------------------------------------

- NOTE -

Verification of setpoint not required for manual initiation functions.

Perform TRIP ACTUATING DEVICE OPERATIONAL 24 months TEST (TADOT).

SR 3.3.2.4 -----------------------------------------------------------------------

- NOTE -

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

Perform CHANNEL CALIBRATION in accordance 24 months with Setpoint Program.

SR 3.3.2.5 Perform CHANNEL OPERATIONAL TEST (COT) in 92 days accordance with Setpoint Program.

SR 3.3.2.6 Verify ESFAS RESPONSE TIMES are within limit. 24 months on a STAGGERED TEST BASIS SR 3.3.2.7 -----------------------------------------------------------------------

- NOTE -

This Surveillance is not required to be performed for actuated equipment which is included in the Inservice Test (IST) Program.

Perform ACTUATION DEVICE TEST. 24 months Turkey Point Unit 7 3.3.2 - 12

Technical Specifications ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.8 Perform ACTUATION DEVICE TEST for squib valves. 24 months SR 3.3.2.9 Perform ACTUATION DEVICE TEST for pressurizer 24 months heater circuit breakers.

Turkey Point Unit 7 3.3.2 - 13

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

1. Safeguards Actuation

a. Manual Initiation 1,2,3,4 2 switches E,O SR 3.3.2.3 5 2 switches G,Y SR 3.3.2.3

b. Containment Pressure - 1,2,3,4 4 B,O SR 3.3.2.1 High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Pressurizer Pressure - 1,2,3(a) 4 B,M SR 3.3.2.1 Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

d. Steam Line Pressure - 1,2,3(a) 4 per steam line B,M SR 3.3.2.1 Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

e. RCS Cold Leg 1,2,3(a) 4 per loop B,M SR 3.3.2.1 Temperature (Tcold) - SR 3.3.2.4 Low SR 3.3.2.5 SR 3.3.2.6 (a) Above the P-11 (Pressurizer Pressure) interlock, when the RCS boron concentration is below that necessary to meet the SDM requirements at an RCS temperature of 200°F.

Turkey Point Unit 7 3.3.2 - 14

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

2. Core Makeup Tank (CMT)

Actuation

a. Manual Initiation 1,2,3,4(b) 2 switches E,N SR 3.3.2.3 4(c), 5(d) 2 switches E,U SR 3.3.2.3 (b)

b. Pressurizer Water Level - 1,2,3,4 4 B,N SR 3.3.2.1 Low 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 4(c), 5(d) 4 B,V SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Safeguards Actuation 1,2,3,4,5(d) Refer to Function 1 (Safeguards Actuation) for initiating functions and requirements.

d. ADS Stages 1, 2, & 3 1,2,3,4,5(d) Refer to Function 9 (ADS Stages 1, 2 & 3 Actuation) for all Actuation initiating functions and requirements.

3. Containment Isolation

a. Manual Initiation 1,2,3,4 2 switches E,O SR 3.3.2.3 5(e), 6(e) 2 switches G,Y SR 3.3.2.3 (e,f) (e,f)

b. Manual Initiation of 1,2,3,4,5 ,6 Refer to Function 12.a (Passive Containment Cooling Actuation)

Passive Containment for initiating functions and requirements.

Cooling

c. Safeguards Actuation 1,2,3,4,5(e) Refer to Function 1 (Safeguards Actuation) for initiating functions and requirements.

(b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(c) With the RCS being cooled by the RNS.

(d) With the RCS pressure boundary intact.

(e) Not applicable for valve isolation Functions whose associated flow path is isolated.

(f) With decay heat > 6.0 MWt.

Turkey Point Unit 7 3.3.2 - 15

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

4. Steam Line Isolation

a. Manual Initiation 1,2(h),3(h),4(h) 2 switches E,S SR 3.3.2.3 (h) (h) (h)

b. Containment Pressure - 1,2 ,3 ,4 4 B,N SR 3.3.2.1 High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Steam Line Pressure (1) Steam Line 1,2(h),3(a,h) 4 per steam line B,M SR 3.3.2.1 Pressure - Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 (2) Steam Line 3(g,h) 4 per steam line B,M SR 3.3.2.1 Pressure - SR 3.3.2.4 Negative SR 3.3.2.5 Rate - High SR 3.3.2.6

d. Tcold - Low 1,2(h),3(a,h) 4 per loop B,M SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

5. Turbine Trip

a. Manual Main Feedwater 1,2 Refer to Function 6.a (Manual Main Feedwater Control Valve Isolation Isolation) for requirements.

b. SG Narrow Range Water 1,2 4 per SG B,L SR 3.3.2.1 Level - High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Reactor Trip 1,2 Refer to Function 18.b (ESFAS Interlocks, Reactor Trip, P-4) for requirements.

(a) Above the P-11 (Pressurizer Pressure) interlock, when the RCS boron concentration is below that necessary to meet the SDM requirements at an RCS temperature of 200°F.

(g) Below the P-11 (Pressurizer Pressure) interlock.

(h) Not applicable if all MSIVs are closed.

Turkey Point Unit 7 3.3.2 - 16

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

6. Main Feedwater Control Valve Isolation

a. Manual Initiation 1,2,3,4(e) 2 switches E,S SR 3.3.2.3

b. SG Narrow Range Water 1,2,3,4(b,e) 4 per SG B,R SR 3.3.2.1 Level - High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Safeguards Actuation 1,2,3,4(e) Refer to Function 1 (Safeguards Actuation) for all initiating functions and requirements.

d. Reactor Coolant Average 1,2 4 B,L SR 3.3.2.1 Temperature SR 3.3.2.4 (Tavg) - Low 1 SR 3.3.2.5 SR 3.3.2.6 Coincident with Reactor Trip 1,2 Refer to Function 18.b (ESFAS Interlocks, Reactor Trip, P-4) for requirements.

7. Main Feedwater Pump Trip and Valve Isolation

a. Manual Initiation Refer to Function 6.a (Manual Main Feedwater Control Valve Isolation) for requirements.

b. SG Narrow Range Water 1,2,3,4(b,e) 4 per SG B,R SR 3.3.2.1 Level - High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Safeguards Actuation 1,2,3,4(e) Refer to Function 1 (Safeguards Actuation) for all initiating functions and requirements.

d. Reactor Coolant Average 1,2 2 per loop B,L SR 3.3.2.1 Temperature SR 3.3.2.4 Tavg - Low 2 SR 3.3.2.5 SR 3.3.2.6 Coincident with Reactor Trip 1,2 Refer to Function 18.b (ESFAS Interlocks, Reactor Trip, P-4) for requirements.

(b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(e) Not applicable for valve isolation Functions whose associated flow path is isolated.

Turkey Point Unit 7 3.3.2 - 17

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

8. Startup Feedwater Isolation

a. SG Narrow Range Water 1,2,3,4(i) 4 per SG B,S SR 3.3.2.1 Level - High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Tcold - Low 1,2,3(a) 4 per loop B,M SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. Manual Initiation Refer to Function 6.a (Manual Main Feedwater Control Valve Isolation) for requirements.

d. SG Narrow Range Water 1,2,3,4(i) 4 per SG B,S SR 3.3.2.1 Level High SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with Reactor Trip Refer to Function 18.b (ESFAS Interlocks, Reactor Trip, P-4) for all requirements.

(P-4)

9. ADS Stages 1, 2 & 3 Actuation

a. Manual Initiation 1,2,3,4 2 switch sets E,O SR 3.3.2.3 5(j),6(j,k) 2 switch sets G,X SR 3.3.2.3

b. Core Makeup Tank (CMT) 1,2,3,4 4 per tank B,O SR 3.3.2.1 Level - Low 1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 5(j,l) 4 per OPERABLE B,V SR 3.3.2.1 tank SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with CMT Refer to Function 2 (CMT Actuation) for all initiating functions and requirements.

Actuation (a) Above the P-11 (Pressurizer Pressure) interlock, when the RCS boron concentration is below that necessary to meet the SDM requirements at an RCS temperature of 200°F.

(i) Not applicable when the startup feedwater flow paths are isolated.

(j) Not applicable when the required ADS valves are open. See LCO 3.4.12 and LCO 3.4.13 for ADS valve and equivalent relief area requirements.

(k) With upper internals in place.

(l) With pressurizer level 20%.

Turkey Point Unit 7 3.3.2 - 18

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

10. ADS Stage 4 Actuation

a. Manual Initiation Coincident 1,2,3,4 2 switch sets E,O SR 3.3.2.3 with 5(j),6(j,k) 2 switch sets G,X SR 3.3.2.3 RCS Wide Range 1,2,3,4 4 B,O SR 3.3.2.1 Pressure - Low, or SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 5(j),6(j,k) 4 B,X SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 ADS Stages 1, 2 & 3 Refer to Function 9 (Stages 1, 2, & 3 Actuation) for initiating functions and requirements Actuation

b. CMT Level - Low 2 1,2,3,4 4 per tank B,O SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 5(j,l) 4 per OPERABLE B,V SR 3.3.2.1 tank SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with RCS Wide 1,2,3,4 4 B,O SR 3.3.2.1 Range Pressure - Low, and SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 5(j,l) 4 B,V SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with ADS Stages 1,2,3,4,5(j,l) Refer to Function 9 (ADS Stages 1, 2 & 3 Actuation) for initiating 1, 2 & 3 Actuation functions and requirements

c. Coincident RCS Loop 1 and 4(c),5(j),6(j) 1 per loop BB,Y SR 3.3.2.1 2 Hot Leg Level - Low 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 (c) With the RCS being cooled by the RNS.

(j) Not applicable when the required ADS valves are open. See LCO 3.4.12 and LCO 3.4.13 for ADS valve and equivalent relief area requirements.

(k) With upper internals in place.

(l) With pressurizer level 20%.

Turkey Point Unit 7 3.3.2 - 19

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 7 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

11. Reactor Coolant Pump Trip

a. ADS Stages 1, 2 & 3 Refer to Function 9 (ADS Stages 1, 2 & 3 Actuation) for initiating functions and requirements.

Actuation

b. Reactor Coolant Pump 1,2 4 per RCP B,L SR 3.3.2.1 Bearing Water SR 3.3.2.4 Temperature - High SR 3.3.2.5 SR 3.3.2.6

c. Manual CMT Actuation Refer to Function 2.a (Manual CMT Actuation) for requirements.

d. Pressurizer Water Level - 1,2,3,4(b) 4 B,N SR 3.3.2.1 Low 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 4(c),5(b,l) 4 B,V SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

e. Safeguards Actuation Refer to Function 1 (Safeguards Actuation) for initiating functions and requirements.

12. Passive Containment Cooling Actuation

a. Manual Initiation 1,2,3,4 2 switches E,O SR 3.3.2.3 (f) (f) 5 ,6 2 switches G,Y SR 3.3.2.3

b. Containment Pressure - 1,2,3,4 4 B,O SR 3.3.2.1 High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 (b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(c) With the RCS being cooled by the RNS.

(f) With decay heat > 6.0 MWt.

(l) With pressurizer level 20%.

Turkey Point Unit 7 3.3.2 - 20

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 8 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

13. Passive Residual Heat Removal Heat Exchanger Actuation

a. Manual Initiation 1,2,3,4 2 switches E,O SR 3.3.2.3 5(d) 2 switches E,U SR 3.3.2.3

b. SG Narrow Range Water 1,2,3,4(b) 4 per SG B,N SR 3.3.2.1 Level - Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with Startup 1,2,3,4(b) 2 per feedwater H,N SR 3.3.2.1 Feedwater Flow - Low line SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

c. SG Wide Range Water Level 1,2,3,4(b) 4 per SG B,N SR 3.3.2.1

- Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

d. ADS Stages 1, 2 & 3 1,2,3,4,5(d) Refer to Function 9 (ADS Stages 1, 2 & 3 Actuation) for initiating Actuation functions and requirements.

e. CMT Actuation Refer to Function 2 (CMT Actuation) for initiating functions and requirements.

f. Pressurizer Water Level, 1,2,3,4(b,m) 4 B,N SR 3.3.2.1 High 3 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

14. SG Blowdown Isolation

a. Passive Residual Heat 1,2,3,4(b,e) Refer to Function 13 (Passive Residual Heat Removal Heat Removal Heat Exchanger Exchanger Actuation) for all initiating functions and requirements.

Actuation

b. SG Narrow Range Water 1,2,3,4(b,e) 4 per SG B,R SR 3.3.2.1 Level - Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 (b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(d) With the RCS pressure boundary intact.

(e) Not applicable for valve isolation Functions whose associated flow path is isolated.

(m) Above the P-19 (RCS Pressure) interlock.

Turkey Point Unit 7 3.3.2 - 21

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 9 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

15. Boron Dilution Block

a. Source Range Neutron Flux 2(n),3(n, e),4(e) 4 B,T SR 3.3.2.1 Doubling SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 5(e) 4 B,P SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Reactor Trip Refer to Function 18.b (ESFAS Interlocks, Reactor Trip, P-4) for all requirements.

16. Chemical Volume and Control System Makeup Isolation

a. SG Narrow Range Water 1,2,3(e),4(b,e) 4 per SG B,R SR 3.3.2.1 Level - High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Pressurizer Water Level - 1,2,3(e) 4 B,Q SR 3.3.2.1 High 1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with Safeguards 1,2,3(e) Refer to Function 1 (Safeguards Actuation) for initiating Actuation functions and requirements.

c. Pressurizer Water Level - 1,2,3,4(b,e,m) 4 B,T SR 3.3.2.1 High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

d. Containment Radioactivity - 1,2,3(e) 4 B,Q SR 3.3.2.1 High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

e. Manual Initiation 1,2,3(e),4(b,e) 2 switches E,R SR 3.3.2.3

f. Source Range Neutron Flux Refer to Function 15.a (Boron Dilution Block, Source Range Neutron Flux Doubling) for all Doubling requirements.

g. SG Narrow Range Water 1,2,3(e),4(b,e) 4 per SG B,R SR 3.3.2.1 Level High SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Coincident with Reactor Trip Refer to Function 18.b (ESFAS Interlocks, Reactor Trip, P-4) for all requirements.

(P-4)

(b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(e) Not applicable for valve isolation Functions whose associated flow path is isolated.

(m) Above the P-19 (RCS Pressure) interlock.

(n) Not applicable when critical or during intentional approach to criticality.

Turkey Point Unit 7 3.3.2 - 22

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 10 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

17. Normal Residual Heat Removal System Isolation

a. Containment Radioactivity - 1,2,3(e) 4 B,Q SR 3.3.2.1 High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Safeguards Actuation 1,2,3(e) Refer to Function 1 (Safeguards Actuation) for all initiating functions and requirements.

c. Manual Initiation 1,2,3(e) 2 switch sets E,Q SR 3.3.2.3

18. ESFAS Interlocks

a. Reactor Trip Breaker Open, 1,2,3 3 divisions D,M SR 3.3.2.3 P-3

b. Reactor Trip, P-4 1,2,3 3 divisions D,M SR 3.3.2.3

c. Intermediate Range Neutron 2 4 J,L SR 3.3.2.1 Flux, P-6 SR 3.3.2.4 SR 3.3.2.5

d. Reactor Coolant Average 2, 3(e),4(e) 4 J,T SR 3.3.2.1 Temperature, P-8 SR 3.3.2.4 SR 3.3.2.5 5(e) 4 J,P SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5

e. Pressurizer Pressure, P-11 1,2,3 4 J,M SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5

f. Pressurizer Level, P-12 1,2,3 4 J,M SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 4,5,6 4 BB,Y SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5

g. RCS Pressure, P-19 1,2,3,4(b) 4 J,N SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5

19. Containment Air Filtration System Isolation

a. Containment Radioactivity - 1,2,3,4(b) 4 B,Z SR 3.3.2.1 High 1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Containment Isolation Refer to Function 3 (Containment Isolation) for initiating functions and requirements.

(b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(e) Not applicable for valve isolation Functions whose associated flow path is isolated.

Turkey Point Unit 7 3.3.2 - 23

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 11 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

20. Main Control Room Isolation, Air Supply Initiation and Electrical Load De-energization

a. Main Control Room Air 1,2,3,4 2 F,O SR 3.3.2.1 Supply Radiation - High 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 Note (o) 2 G,K SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

21. Auxiliary Spray and Purification Line Isolation

a. Pressurizer Water Level - 1,2 4 B,L SR 3.3.2.1 Low 1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Manual Initiation 1,2 Refer to Function 16.e (Manual Chemical Volume Control System (Makeup Isolation) for requirements.

22. In-Containment Refueling Water Storage Tank (IRWST) Injection Line Valve Actuation

a. Manual Initiation 1,2,3,4(b) 2 switch sets E,N SR 3.3.2.3 (c) 4 ,5,6 2 switch sets G,Y SR 3.3.2.3

b. ADS 4th Stage Actuation Refer to Function 10 (ADS 4th Stage Actuation) for initiating functions and requirements.

23. IRWST Containment Recirculation Valve Actuation

a. Manual Initiation 1,2,3,4(b) 2 switch sets E,N SR 3.3.2.3 4(c),5,6 2 switch sets G,Y SR 3.3.2.3

b. ADS Stage 4 Actuation Refer to Function 10 (ADS Stage 4 Actuation) for all initiating functions and requirements.

Coincident with IRWST 1,2,3,4(b) 4 B,N SR 3.3.2.1 Level - Low 3 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 4(c),5(j),6(j) 4 I,Y SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 (b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(c) With the RCS being cooled by the RNS.

(j) Not applicable when the required ADS valves are open. See LCO 3.4.12 and LCO 3.4.13 for ADS valve and equivalent relief area requirements.

(o) During movement of irradiated fuel assemblies.

Turkey Point Unit 7 3.3.2 - 24

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 12 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

24. Refueling Cavity Isolation

a. Spent Fuel Pool 6 3 H,P SR 3.3.2.1 Level - Low SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

25. ESF Coincidence Logic

a. Coincidence Logic 1,2,3,4 4 divisions, D,O SR 3.3.2.2 1 battery-backed subsystem per division 5,6 4 divisions, G,W SR 3.3.2.2 1 battery-backed subsystem per division

26. ESF Actuation

a. ESF Actuation 1,2,3,4 4 divisions, D,O SR 3.3.2.2 Subsystem 1 battery-backed SR 3.3.2.7 subsystem per SR 3.3.2.8 division 5,6 4 divisions, G,W SR 3.3.2.2 1 battery-backed SR 3.3.2.7 subsystem per division

27. Pressurizer Heater Trip

a. Core Makeup Tank 1,2,3,4(b,m) Refer to Function 2 (Core Makeup Tank Actuation) for all initiating Actuation functions and requirements. In addition to the requirements for Function 2, SR 3.3.2.9 also applies.

b. Pressurizer Water 1,2,3,4(b,m) 4 B,N SR 3.3.2.1 Level, High 3 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

28. Chemical and Volume Control System Letdown Isolation

a. Hot Leg Level - 4(c,p),5(p),6(p,q) 1 per loop C,AA SR 3.3.2.1 Low 1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 (b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(c) With the RCS being cooled by the RNS.

(m) Above the P-19 (RCS Pressure) interlock.

(p) Below the P-12 (Pressurizer Level) interlock.

(q) With the water level < 23 feet above the top of the reactor vessel flange.

Turkey Point Unit 7 3.3.2 - 25

Technical Specifications ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 13 of 13)

Engineered Safeguards Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS

29. SG Power Operated Relief Valve and Block Valve Isolation

a. Manual Initiation 1,2,3,4(b) 2 switches E,N SR 3.3.2.3

b. Steam Line Pressure - Low 1,2,3,4(b) 4 per steam line B,N SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

30. Component Cooling Water System Containment Isolation Valve Closure

a. Reactor Coolant Pump 1,2,3,4 4 per RCP B,T SR 3.3.2.1 Bearing Water SR 3.3.2.4 Temperature - High SR 3.3.2.5 SR 3.3.2.6

31. Containment Vacuum Relief Valve Actuation

a. Containment Pressure - 1,2,3,4,5(r),6(r) 4 B,CC SR 3.3.2.1 Low 2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6

b. Manual Initiation 1,2,3,4,5(r),6(r) 2 switches E,CC SR 3.3.2.3 (b) With the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

(r) Without an open containment air flow path 6 inches in diameter.

Turkey Point Unit 7 3.3.2 - 26

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

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

- NOTES -

1. LCO 3.0.4 not applicable.

2. Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore required channel 30 days with one required to OPERABLE status.

channel inoperable.

B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.7.

met.

C. One or more Functions C.1 Restore one channel to 7 days with two required OPERABLE status.

channels inoperable.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition C not for the channel.

met.

E. As required by Required E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in AND Table 3.3.3-1.

E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.3.3 - 1

Technical Specifications PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

- NOTE -

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

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 -----------------------------------------------------------------------

- NOTE -

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 24 months Turkey Point Unit 7 3.3.3 - 2

Technical Specifications PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1)

Post-Accident Monitoring Instrumentation CONDITION REQUIRED REFERENCED CHANNELS/ FROM REQUIRED FUNCTION DIVISIONS ACTION D.1

1. Neutron Flux (Intermediate Range) 2 E

2. Reactor Coolant System (RCS) Hot Leg Temperature (Wide Range) 2 E

3. RCS Cold Leg Temperature (Wide Range) 2 E

4. RCS Pressure (Wide Range) 2 E (a)

5. Pressurizer Pressure and RCS Subcooling Monitor 2 E

6. Containment Water Level 2 E

7. Containment Pressure 2 E

8. Containment Pressure (Extended Range) 2 E

9. Containment Area Radiation (High Range) 2 E

10. Pressurizer Level and Associated Reference Leg Temperature 2 E

11. In-Containment Refueling Water Storage Tank (IRWST) Water Level 2 E

12. Passive Residual Heat Removal (PRHR) Flow and PRHR Outlet 2 flow & E Temperature 1 temperature

13. Core Exit Temperature -- Quadrant 1 2(b) E

14. Core Exit Temperature -- Quadrant 2 2(b) E (b)

15. Core Exit Temperature -- Quadrant 3 2 E (b)

16. Core Exit Temperature -- Quadrant 4 2 E

17. Passive Containment Cooling System (PCS) Storage Tank Level and PCS 2 level & 1 flow E Flow

18. Remotely Operated Containment Isolation Valve Position 1/valve(c) E

19. IRWST to Normal Residual Heat Removal System (RNS) Suction Valve 2 E Status (a) RCS Subcooling calculated from pressurizer pressure and RCS hot leg temperature.

(b) A channel consists of two thermocouples within a single division. Each quadrant contains two divisions. The minimum requirement is two OPERABLE thermocouples in each of the two divisions.

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

Turkey Point Unit 7 3.3.3 - 3

Technical Specifications RSW 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown Workstation (RSW)

LCO 3.3.4 The RSW shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with Reactor Coolant System (RCS) average temperature (Tavg) 350°F.

ACTIONS

- NOTE -

LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. RSW inoperable. A.1 Restore to OPERABLE 30 days status.

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

B.2 Be in MODE 4 with 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Tavg < 350°F.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Verify each required transfer switch is capable of 24 months performing the required function.

SR 3.3.4.2 Verify that the RSW communicates indication and 24 months controls with Division A, B, C and D of the Protection and Safety Monitoring System (PMS).

SR 3.3.4.3 Verify the OPERABILITY of the RSW hardware and 24 months software.

Turkey Point Unit 7 3.3.4 - 1

Technical Specifications RSW 3.3.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.4 Perform TADOT of the reactor trip breaker 24 months open/closed indication.

Turkey Point Unit 7 3.3.4 - 2

Technical Specifications DAS Manual Controls 3.3.5 3.3 INSTRUMENTATION 3.3.5 Diverse Actuation System (DAS) Manual Controls LCO 3.3.5 The DAS manual controls for each function in Table 3.3.5-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more manual A.1 Restore DAS manual 30 days DAS controls controls to OPERABLE inoperable. status.

B. Required Action and B.1 Perform SR 3.3.1.6. Once per 31 days on a associated Completion STAGGERED TEST Time of Condition A not AND BASIS met for inoperable DAS manual reactor trip B.2 Restore all controls to Prior to entering control. OPERABLE status. MODE 2 following next MODE 5 entry C. Required Action and C.1 Perform SR 3.3.2.2. Once per 31 days on a associated Completion STAGGERED TEST Time of Condition A not AND BASIS met for inoperable DAS manual actuation C.2 Restore all controls to Prior to entering control other than OPERABLE status. MODE 2 following reactor trip. next MODE 5 entry D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not AND met.

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Required Action and associated Completion Time of Condition C not met.

Turkey Point Unit 7 3.3.5 - 1

Technical Specifications DAS Manual Controls 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 -----------------------------------------------------------------------

- NOTE -

Verification of setpoint not required.

Perform TRIP ACTUATION DEVICE OPERATIONAL 24 months TEST (TADOT).

Turkey Point Unit 7 3.3.5 - 2

Technical Specifications DAS Manual Controls 3.3.5 Table 3.3.5-1 (page 1 of 1)

DAS Manual Controls APPLICABLE MODES OR OTHER SPECIFIED REQUIRED FUNCTION CONDITIONS CONTROLS

1. Reactor trip manual controls 1,2 2 switches

2. Passive Residual Heat Removal Heat 1,2,3,4,5(a) 2 switches Exchanger (PRHR HX) control and In-Containment Refueling Water Storage Tank (IRWST) gutter control valves

3. Core Makeup Tank (CMT) isolation valves 1,2,3,4,5(a) 2 switches

4. Automatic Depressurization System (ADS) 1,2,3,4,5(a) 2 switches stage 1 valves

5. ADS stage 2 valves 1,2,3,4,5(a) 2 switches

6. ADS stage 3 valves 1,2,3,4,5(a) 2 switches

7. ADS stage 4 valves 1,2,3,4,5,6(c) 2 switches

8. IRWST injection squib valves 1,2,3,4,5,6 2 switches

9. Containment recirculation valves 1,2,3,4,5,6 2 switches

10. Passive containment cooling drain valves 1,2,3,4,5(b),6(b) 2 switches

11. Selected containment isolation valves 1,2,3,4,5,6 2 switches (a) With Reactor Coolant System (RCS) pressure boundary intact.

(b) With the calculated reactor decay heat > 6.0 MWt.

(c) In MODE 6 with reactor internals in place.

Turkey Point Unit 7 3.3.5 - 3

Technical Specifications RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified below:

a. Pressurizer Pressure is greater than or equal to the limit specified in the COLR

b. RCS Average Temperature is less than or equal to the limit specified in the COLR, and

c. RCS total flow rate 301,670 gpm and greater than or equal to the limit specified in the COLR.

APPLICABILITY: MODE 1.

- NOTE -

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp > 5% RTP per minute, or

b. THERMAL POWER step > 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months parameters not within parameter(s) to within limit.

limits.

B. Required Action B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time not met.

Turkey Point Unit 7 3.4.1 - 1

Technical Specifications RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is greater than or equal to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the limit specified in the COLR.

SR 3.4.1.2 Verify RCS average temperature is less than or equal 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to the limit specified in the COLR.

SR 3.4.1.3 Verify RCS total flow rate is 301,670 gpm and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months greater than or equal to the limit specified in the COLR.

SR 3.4.1.4 Perform a CHANNEL CALIBRATION of RCS total 24 months flow rate indication (differential pressure) channels.

SR 3.4.1.5 -----------------------------------------------------------------------

- NOTE -

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after 90% RTP.

Verify that RCS total flow rate is 301,670 gpm and 24 months greater than or equal to the limit specified in the COLR as determined by precision heat balance or RCS total flow rate indication (differential pressure) measurements.

Turkey Point Unit 7 3.4.1 - 2

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

APPLICABILITY: MODE 1, MODE 2 with keff 1.0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Tavg in one or more RCS A.1 Be in MODE 2 with 30 minutes loops not within limit. keff < 1.0.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop 551°F. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.4.2 - 1

Technical Specifications RCS P/T Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (P/T) Limits LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in the PTLR.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------------------------------- A.1 Restore parameters to 30 minutes

- NOTE - within limits.

Required Action A.2 shall be completed AND whenever this Condition is entered. A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

acceptable for continued operation.

Requirements of LCO not met in MODE 1, 2, 3, or 4.

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

B.2 Be in MODE 4 with RCS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pressure < 500 psig.

C. -------------------------------- C.1 Initiate action to restore Immediately

- NOTE - parameter(s) to within Required Action C.2 limits.

shall be completed whenever this Condition AND is entered.

C.2 Determine RCS is Prior to entering acceptable for continued MODE 4 Requirements of LCO operation.

not met any time in other than MODE 1, 2, 3, or 4.

Turkey Point Unit 7 3.4.3 - 1

Technical Specifications RCS P/T Limits 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 -----------------------------------------------------------------------

- NOTE -

Only required to be performed during RCS heatup and cooldown operations and inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and RCS 30 minutes heatup and cooldown rates within limits specified in the PTLR.

Turkey Point Unit 7 3.4.3 - 2

Technical Specifications RCS Loops 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops LCO 3.4.4 Two RCS loops shall be OPERABLE with four Reactor Coolant Pumps (RCPs) in operation with variable speed control bypassed.

- NOTES -

1. No RCP shall be started when the reactor trip breakers are closed.

2. No RCP shall be started when the RCS temperature is 350°F unless pressurizer level is < 92%.

3. No RCP shall be started with any RCS cold leg temperature 350°F unless the secondary side water temperature of each steam generator (SG) is 50°F above each of the RCS cold leg temperatures and the RCP is started at 25% of RCP speed.

4. All RCPs may be de-energized in MODE 3, 4, or 5 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

APPLICABILITY: MODES 1 and 2, MODES 3, 4, and 5, whenever the reactor trip breakers are closed.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------------------------------- A.1 Be in MODE 3 with the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

- NOTE - reactor trip breakers open.

Required Action A.1 must be completed whenever Condition A is entered.

Requirements of LCO not met in MODE 1 or 2.

Turkey Point Unit 7 3.4.4 - 1

Technical Specifications RCS Loops 3.4.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. -------------------------------- B.1 Open reactor trip breakers. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

- NOTE -

Required Action B.1 must be completed whenever Condition B is entered.

Requirements of LCO not met in MODE 3, 4, or 5.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation with variable 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months speed control bypassed.

Turkey Point Unit 7 3.4.4 - 2

Technical Specifications Pressurizer 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 Pressurizer LCO 3.4.5 The pressurizer water level shall be 92% of span.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water level A.1 Restore pressurizer water 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not within limit. level within limit.

OR A.2.1 Be in MODE 3 with reactor 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trip breakers open.

AND A.2.2 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 3.4.5.1 Verify pressurizer water level 92% of span. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.4.5 - 1

Technical Specifications Pressurizer Safety Valves 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 Pressurizer Safety Valves LCO 3.4.6 Two pressurizer safety valves shall be OPERABLE with lift settings 2460 psig and 2510 psig.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with Normal Residual Heat Removal System (RNS) isolated or RCS temperature 275°F.

- NOTE -

The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions.

This exception is allowed for 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-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 A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status.

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

B.2 Be in MODE 4 with RNS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR aligned to the RCS and RCS temperature < 275°F.

Two pressurizer safety valves inoperable.

Turkey Point Unit 7 3.4.6 - 1

Technical Specifications Pressurizer Safety Valves 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify each pressurizer safety valve OPERABLE in In accordance with accordance with the Inservice Testing Program. the Inservice Following testing, lift settings shall be within +/-1%. Testing Program Turkey Point Unit 7 3.4.6 - 2

Technical Specifications RCS Operational LEAKAGE 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Operational LEAKAGE LCO 3.4.7 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE,

b. 0.5 gpm unidentified LEAKAGE,

c. 10 gpm identified LEAKAGE from the RCS,

d. 150 gallons per day primary to secondary LEAKAGE through any one Steam Generator (SG), and

e. 500 gallons per day primary to In-Containment Refueling Water Storage Tank (IRWST) LEAKAGE through the passive residual heat removal heat exchanger (PRHR HX).

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

Turkey Point Unit 7 3.4.7 - 1

Technical Specifications RCS Operational LEAKAGE 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 -----------------------------------------------------------------------

- NOTES -

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

2. Not applicable to primary to secondary LEAKAGE.

Verify RCS operational LEAKAGE is within limits by 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months performance of RCS water inventory balance.

SR 3.4.7.2 -----------------------------------------------------------------------

- NOTE -

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

Verify primary to secondary LEAKAGE is 150 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months gallons per day through any one SG.

Turkey Point Unit 7 3.4.7 - 2

Technical Specifications Minimum RCS Flow 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 Minimum RCS Flow LCO 3.4.8 At least one Reactor Coolant Pump (RCP) shall be in operation with a total flow through the core of at least 3,000 gpm.

- NOTES -

1. All RCPs may be de-energized for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

2. No RCP shall be started when the RCS temperature is 350°F unless pressurizer level is < 92%.

3. No RCP shall be started with any RCS cold leg temperature 350°F unless the secondary side water temperature of each steam generator (SG) is 50°F above each of the RCS cold leg temperatures and the RCP is started at 25% of RCP speed.

APPLICABILITY: MODES 3, 4, and 5, whenever the reactor trip breakers are open and with unborated water sources not isolated from the RCS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No RCP in operation. A.1 Isolate all sources of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months unborated water.

AND A.2 Perform SR 3.1.1.1. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Turkey Point Unit 7 3.4.8 - 1

Technical Specifications Minimum RCS Flow 3.4.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify that at least one RCP is in operation at 10% 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months rated speed or equivalent.

Turkey Point Unit 7 3.4.8 - 2

Technical Specifications RCS Leakage Detection Instrumentation 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 RCS Leakage Detection Instrumentation LCO 3.4.9 The following RCS leakage detection instrumentation shall be OPERABLE:

a. Two containment sump level channels;

b. One containment atmosphere radioactivity monitor (F18 particulate).

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

- NOTES -

1. The F18 particulate containment atmosphere radioactivity monitor is only required to be OPERABLE in MODE 1 with RTP > 20%.

2. Containment sump level measurements cannot be used for leak detection if leakage is prevented from draining to the sump such as by redirection to the In-Containment Refueling Water Storage Tank (IRWST) by the containment shell gutter drains.

ACTIONS

- NOTE LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Verify that the volume input Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months containment sump per day to the containment channel inoperable. sump does not change

(+ or -) more than 10 gallons or 33% of the volume input (whichever is greater). The volume used for comparison will be the value taken during the first day following the entrance into this CONDITION.

AND Turkey Point Unit 7 3.4.9 - 1

Technical Specifications RCS Leakage Detection Instrumentation 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 Restore two containment 14 days sump channels to OPERABLE status.

B. Two required B.1 -----------------------------------

containment sump - NOTE -

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

Perform SR 3.4.7.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND B.2 Restore one containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months sump channel to OPERABLE status.

C. Required containment C.1.1 Analyze grab samples of Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months atmosphere containment atmosphere.

radioactivity monitor inoperable. OR C.1.2 -----------------------------------

- NOTE -

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

Perform SR 3.4.7.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND C.2 Restore containment 30 days atmosphere radioactivity monitor to OPERABLE status.

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

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Turkey Point Unit 7 3.4.9 - 2

Technical Specifications RCS Leakage Detection Instrumentation 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. All required monitors E.1 Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Perform a CHANNEL CHECK of required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months containment atmosphere radioactivity monitor.

SR 3.4.9.2 Perform a COT of required containment atmosphere 92 days radioactivity monitor.

SR 3.4.9.3 Perform a CHANNEL CALIBRATION of required 24 months containment sump monitor.

SR 3.4.9.4 Perform a CHANNEL CALIBRATION of required 24 months containment atmosphere radioactivity monitor.

Turkey Point Unit 7 3.4.9 - 3

Technical Specifications RCS Specific Activity 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 RCS Specific Activity LCO 3.4.10 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 > 1.0 Ci/gm. - NOTE -

LCO 3.0.4 is not applicable.

A.1 Verify DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT I-131 to be 60 Ci/gm.

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT I-131 to within limit.

B. DOSE EQUIVALENT B.1 Perform SR 3.4.10.2. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months XE-133 > 280 Ci/gm.

AND B.2 Be in MODE 3 with Tavg 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

< 500°F.

C. Required Action C.1 Be in MODE 3 with Tavg 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated < 500°F.

Completion Time of Condition A not met.

OR DOSE EQUIVALENT I-131 > 60 Ci/gm.

Turkey Point Unit 7 3.4.10 - 1

Technical Specifications RCS Specific Activity 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify reactor coolant DOSE EQUIVALENT XE-133 7 days specific activity < 280 Ci/gm.

SR 3.4.10.2 -----------------------------------------------------------------------

- NOTE -

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT I-131 14 days specific activity 1.0 Ci/gm.

AND Between 2 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of 15% of RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period Turkey Point Unit 7 3.4.10 - 2

Technical Specifications ADS - Operating 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Automatic Depressurization System (ADS) - Operating LCO 3.4.11 The ADS, including 10 flow paths, shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One stage 1, 2, or 3 A.1 Restore flow path to 7 days ADS flow path OPERABLE status.

inoperable.

B. One stage 4 ADS flow B.1 Restore flow path to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months path inoperable. OPERABLE status.

C. Two or three ADS flow C.1 Restore flow paths to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months paths inoperable with a OPERABLE status.

combined inoperable flow capacity less than or equal to that of a division with the largest ADS flow capacity.

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

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Requirements of LCO not met for reasons other than Condition A, B, or C.

Turkey Point Unit 7 3.4.11 - 1

Technical Specifications ADS - Operating 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify that the motor operated valve in series with 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months each 4th stage ADS valve is fully open.

SR 3.4.11.2 Verify that each stage 1, 2, and 3 ADS valve is In accordance with OPERABLE by stroking them open. the Inservice Testing Program SR 3.4.11.3 Verify that each stage 4 ADS valve is OPERABLE in In accordance with accordance with the Inservice Testing Program. the Inservice Testing Program Turkey Point Unit 7 3.4.11 - 2

Technical Specifications ADS - Shutdown, RCS Intact 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Automatic Depressurization System (ADS) - Shutdown, RCS Intact LCO 3.4.12 The ADS, including 9 flow paths, shall be OPERABLE.

APPLICABILITY: MODE 5 with RCS pressure boundary intact.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required stage 1, 2, A.1 Restore flow path to 7 days or 3 ADS flow path OPERABLE status.

inoperable.

B. One required stage 4 B.1 Restore flow path to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ADS flow path OPERABLE status.

inoperable.

C. Two or three required C.1 Restore flow paths to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ADS flow paths OPERABLE status.

inoperable with a combined inoperable flow capacity less than or equal to that of a division with the largest ADS flow capacity.

D. Required Action D.1 Initiate action to be in Immediately and associated MODE 5, with RCS open Completion Time and 20% pressurizer not met. level.

OR Requirements of LCO not met for reasons other than Condition A, B, or C.

Turkey Point Unit 7 3.4.12 - 1

Technical Specifications ADS - Shutdown, RCS Intact 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 For flow paths required to be OPERABLE, the SRs of In accordance with LCO 3.4.11, Automatic Depressurization System applicable SRs (ADS) - Operating are applicable.

Turkey Point Unit 7 3.4.12 - 2

Technical Specifications ADS - Shutdown, RCS Open 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 Automatic Depressurization System (ADS) - Shutdown, RCS Open LCO 3.4.13 ADS stage 1, 2, and 3, flow paths shall be open.

ADS stage 4 with 2 flow paths shall be OPERABLE.

- NOTE -

In MODE 5, the ADS valves may be closed to facilitate RCS vacuum fill operations to establish a pressurizer level 20%, provided ADS valve OPERABILITY meets LCO 3.4.12, ADS - Shutdown, RCS Intact.

APPLICABILITY: MODE 5 with RCS pressure boundary open or pressurizer level < 20%;

MODE 6 with upper internals in place.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ADS A.1 Open the affected flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months stage 1, 2, or 3 flow path.

path not open.

OR A.2 Open an alternative flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months path with an equivalent area.

B. One required ADS B.1 Open an alternative flow 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months stage 4 flow path closed path with an equivalent and inoperable. area.

OR B.2 Restore two ADS stage 4 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months flow paths to OPERABLE status.

Turkey Point Unit 7 3.4.13 - 1

Technical Specifications ADS - Shutdown, RCS Open 3.4.13 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action C.1 Initiate action to fill the Immediately and associated RCS to establish 20%

Completion Time not pressurizer level.

met while in MODE 5.

AND OR C.2 Suspend positive reactivity Immediately Requirements of LCO additions.

not met for reasons other than Conditions A or B while in MODE 5.

D. Required Action D.1 Initiate action to remove Immediately and associated the upper internals.

Completion Time not met while in MODE 6. AND OR D.2 Suspend positive reactivity Immediately additions.

Requirements of LCO not met for reasons other than Conditions A or B while in MODE 6.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 Verify that each ADS stage 1, 2, and 3 valve is in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months fully open position.

SR 3.4.13.2 For each ADS stage 4 flow path required to be In accordance with OPERABLE, the following SRs of LCO 3.4.11, applicable SRs Automatic Depressurization System (ADS) -

Operating are applicable:

SR 3.4.11.1 SR 3.4.11.3 Turkey Point Unit 7 3.4.13 - 2

Technical Specifications LTOP System 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.14 At least one of the following Overpressure Protection Systems shall be OPERABLE, with the accumulators isolated:

a. The Normal Residual Heat Removal System (RNS) suction relief valve with lift setting within the limit specified in the PTLR, or

b. The RCS depressurized and an RCS vent of 4.15 square inches.

- NOTE -

1. No reactor coolant pump (RCP) shall be started when the RCS temperature is 350°F unless pressurizer level is < 92%.

2. No RCP shall be started with any RCS cold leg temperature 350°F unless the secondary side water temperature of each steam generator (SG) is 50°F above each of the RCS cold leg temperatures and the RCP is started at 25% of RCP speed.

APPLICABILITY: MODE 4 when any cold leg temperature is 275°F, MODE 5, MODE 6 when the reactor vessel head is on.

- NOTE -

Accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

Turkey Point Unit 7 3.4.14 - 1

Technical Specifications LTOP System 3.4.14 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. An accumulator not A.1 Isolate affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolated when the accumulator.

accumulator pressure is

> to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

B. Required Action B.1 Increase RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and associated temperature to a level Completion Time of acceptable for the existing Condition A not met. accumulator pressure allowed in the PTLR.

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

C. The RNS suction relief C.1 Restore the RNS suction 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months valve inoperable. relief valve to OPERABLE status.

OR C.2 Depressurize RCS and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months establish RCS vent of 4.15 square inches.

Turkey Point Unit 7 3.4.14 - 2

Technical Specifications LTOP System 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 Verify each accumulator is isolated. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.14.2 Verify both RNS suction isolation valves in one RNS 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months suction flow path are open.

SR 3.4.14.3 -----------------------------------------------------------------------

- NOTE -

Only required to be performed when complying with LCO 3.4.14.b.

Verify RCS vent 4.15 square inches is open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked-open vent AND 31 days for locked-open vent SR 3.4.14.4 Verify the lift setting of the RNS suction relief valve. In accordance with the Inservice Testing Program Turkey Point Unit 7 3.4.14 - 3

Technical Specifications RCS PIV Integrity 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Pressure Isolation Valve (PIV) Integrity LCO 3.4.15 Leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4, with the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

ACTIONS

- NOTES -

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.

CONDITION REQUIRED ACTION COMPLETION TIME A. Leakage from one or ---------------------------------------------

more RCS PIVs not NOTE -

within limit.

Each valve used to satisfy Required Action A.1 and Required Action A.2 must have been verified to meet SR 3.4.15.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system.

A.1 Isolate the high pressure 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND Turkey Point Unit 7 3.4.15 - 1

Technical Specifications RCS PIV Integrity 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 Verify a second 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE PIV can meet the leakage limits. This valve is required to be a check valve, or a closed valve, if it isolates a line that penetrates containment.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Verify leakage of each RCS PIV is equivalent to 24 months 0.5 gpm per nominal inch valve size up to a maximum of 5 gpm at an RCS pressure 2215 and 2255 psig.

Turkey Point Unit 7 3.4.15 - 2

Technical Specifications RVHV 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 Reactor Vessel Head Vent (RVHV)

LCO 3.4.16 The Reactor Vessel Head Vent shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with the RCS not being cooled by the Normal Residual Heat Removal System (RNS).

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

B. Two flow paths B.1 Restore at least one flow 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months inoperable. path to OPERABLE status.

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

C.2 Be in MODE 4, with the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR RCS cooling provided by the RNS.

Requirements of LCO not met for reasons other than Conditions A or B.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify that each RVHV valve is OPERABLE by In accordance with stroking it open. the Inservice Testing Program Turkey Point Unit 7 3.4.16 - 1

Technical Specifications CVS Makeup Isolation Valves 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Chemical and Volume Control System (CVS) Makeup Isolation Valves LCO 3.4.17 Two CVS Makeup Isolation Valves shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CVS makeup A.1 Restore two CVS makeup 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months isolation valve isolation valves to inoperable. OPERABLE status.

B. Required Action B.1 ------------------------------------

and associated - NOTE -

Completion Time not Flow path(s) may be met. unisolated intermittently under administrative OR controls.

Two CVS makeup isolation valves Isolate the flow path from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. the CVS makeup pumps to the Reactor Coolant System by use of at least one closed manual or one closed and de-activated automatic valve.

Turkey Point Unit 7 3.4.17 - 1

Technical Specifications CVS Makeup Isolation Valves 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify two CVS makeup isolation valves are In accordance with OPERABLE by stroking the valves closed. the Inservice Testing Program SR 3.4.17.2 Verify closure time of each CVS makeup isolation In accordance with valve is 30 seconds on an actual or simulated the Inservice actuation signal. Testing Program Turkey Point Unit 7 3.4.17 - 2

Technical Specifications SG Tube Integrity 3.4.18 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.18 Steam Generator (SG) Tube Integrity LCO 3.4.18 SG tube integrity shall be maintained.

AND All SG tubes satisfying the tube repair criteria shall be plugged 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 A.1 Verify tube integrity of the 7 days satisfying the tube affected tube(s) is repair criteria and not maintained until the next plugged in accordance refueling outage or SG with the Steam tube inspection.

Generator Program.

AND A.2 Plug the affected tube(s) in Prior to entering accordance with the Steam MODE 4 following the Generator Program. next refueling outage or SG tube inspection B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

Turkey Point Unit 7 3.4.18 - 1

Technical Specifications SG Tube Integrity 3.4.18 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.18.1 Verify SG tube integrity in accordance with the Steam In accordance with Generator Program. the Steam Generator Program SR 3.4.18.2 Verify that each inspected SG tube that satisfies the Prior to entering tube repair criteria is plugged in accordance with the MODE 4 following Steam Generator Program. a SG tube inspection Turkey Point Unit 7 3.4.18 - 2

Technical Specifications Accumulators 3.5.1 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.1 Accumulators LCO 3.5.1 Both accumulators shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

MODES 3 and 4 with Reactor Coolant System (RCS) pressure

> 1000 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A.1 Restore boron 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to boron concentration to within concentration outside limits.

limits.

B. One accumulator B.1 Restore accumulator to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months if Condition C inoperable for reasons OPERABLE status. or E of LCO 3.5.2 has other than Condition A. not been entered OR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if Condition C or E of LCO 3.5.2 has been entered C. Required Action C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time of AND Condition A or B not met. C.2 Reduce RCS pressure to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1000 psig.

D. Two accumulators D.1 Enter LCO 3.0.3. Immediately inoperable.

Turkey Point Unit 7 3.5.1 - 1

Technical Specifications Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.1.2 Verify the borated water volume in each accumulator 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is 1667 cu. ft., and 1732 cu. ft.

SR 3.5.1.3 Verify the nitrogen cover gas pressure in each 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator is 637 psig and 769 psig.

SR 3.5.1.4 Verify the boron concentration in each accumulator is 31 days 2600 ppm and 2900 ppm.

AND

- NOTE -

Only required for affected accumulators.

Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of 51 cu. ft., 3.0%

that is not the result of addition from the in-containment refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator 31 days isolation valve operator when pressurizer pressure is 2000 psig.

SR 3.5.1.6 Verify system flow performance of each accumulator 10 years in accordance with the System Level OPERABILITY Testing Program.

Turkey Point Unit 7 3.5.1 - 2

Technical Specifications CMTs - Operating 3.5.2 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.2 Core Makeup Tanks (CMTs) - Operating LCO 3.5.2 Both CMTs shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with the Reactor Coolant System (RCS) not being cooled by the Normal Residual Heat Removal System (RNS).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CMT inoperable A.1 Restore outlet isolation 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months due to one CMT outlet valve to OPERABLE isolation valve status.

inoperable.

B. One CMT inoperable B.1 Restore water temperature 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months due to one or more or boron concentration to parameters (water within limits.

temperature, boron concentration) not within limits.

C. Two CMTs inoperable C.1 Restore water temperature 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months if Condition B due to water or boron concentration to of LCO 3.5.1 has not temperature or boron within limits for one CMT. been entered concentration not within limits. OR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if Condition B of LCO 3.5.1 has been entered D. One CMT inoperable D.1 Vent noncondensible 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months due to presence of non- gases.

condensible gases in one high point vent.

E. One CMT inoperable for E.1 Restore CMT to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months if Condition B reasons other than OPERABLE status. of LCO 3.5.1 has not Condition A, B, C, or D. been entered OR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if Condition B of LCO 3.5.1 has been entered Turkey Point Unit 7 3.5.2 - 1

Technical Specifications CMTs - Operating 3.5.2 ACTIONS (continued)

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

F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR LCO not met for reasons other than A, B, C, D, or E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the temperature of the borated water in each 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months CMT is < 120°F.

SR 3.5.2.2 Verify the borated water volume in each CMT is 7 days 2500 cu. ft.

SR 3.5.2.3 Verify each CMT inlet isolation valve is fully open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.2.4 Verify the volume of noncondensible gases in each 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months CMT inlet line has not caused the high-point water level to drop below the sensor.

SR 3.5.2.5 Verify the boron concentration in each CMT is 7 days 3400 ppm, and 3700 ppm.

SR 3.5.2.6 Verify each CMT outlet isolation valve is OPERABLE In accordance with by stroking it open. the Inservice Testing Program SR 3.5.2.7 Verify system flow performance of each CMT in 10 years accordance with the System Level OPERABILITY Testing Program.

Turkey Point Unit 7 3.5.2 - 2

Technical Specifications CMTs - Shutdown, RCS Intact 3.5.3 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.3 Core Makeup Tanks (CMTs) - Shutdown, Reactor Coolant System (RCS) Intact LCO 3.5.3 One CMT shall be OPERABLE.

APPLICABILITY: MODE 4 with the RCS cooling provided by the Normal Residual Heat Removal System (RNS).

MODE 5 with the RCS pressure boundary intact.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required CMT A.1 Restore required isolation 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to one valve to OPERABLE outlet isolation valve status.

inoperable.

B. Required CMT B.1 Restore water temperature 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to one or boron concentration to or more parameters within limits.

(water temperature, boron concentration) not within limits.

C. Required CMT C.1 Restore required CMT to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for reasons OPERABLE status.

other than A or B.

D. Required Action D.1 Initiate action to be in Immediately and associated MODE 5 with RCS Completion Time not pressure boundary open met. and 20% pressurizer level.

OR LCO not met for reasons other than A, B, or C.

Turkey Point Unit 7 3.5.3 - 1

Technical Specifications CMTs - Shutdown, RCS Intact 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 For the CMT required to be OPERABLE, the SRs of In accordance with Specification 3.5.2, Core Makeup Tanks (CMTs) - applicable SRs Operating are applicable.

Turkey Point Unit 7 3.5.3 - 2

Technical Specifications PRHR HX - Operating 3.5.4 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.4 Passive Residual Heat Removal Heat Exchanger (PRHR HX) - Operating LCO 3.5.4 The PRHR HX shall be OPERABLE.

- NOTE -

When any reactor coolant pumps (RCPs) are operating, at least one RCP must be operating in the loop with the PRHR HX, Loop 1.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with the Reactor Coolant System (RCS) not being cooled by the Normal Residual Heat Removal System (RNS).

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

B. One air operated In- B.1 Restore air operated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Containment Refueling IRWST gutter isolation Water Storage Tank valve to OPERABLE (IRWST) gutter isolation status.

valve inoperable.

C. Presence of non- C.1 Vent noncondensible 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months condensible gases in gases.

the high point vent.

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

D.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RCS cooling provided by the RNS.

E. LCO not met for E.1 Restore PRHR HX to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months reasons other than OPERABLE status.

Condition A, B, or C.

Turkey Point Unit 7 3.5.4 - 1

Technical Specifications PRHR HX - Operating 3.5.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action F.1 ------------------------------------

and associated - NOTE -

Completion Time of Prior to initiating actions to Condition E not met. change to a lower MODE, verify that redundant means of providing Steam Generator (SG) feedwater are OPERABLE. If redundant means are not OPERABLE, suspend LCO 3.0.3 and all other LCO Required Actions requiring MODE changes until redundant means are restored to OPERABLE status.

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

- NOTE -

Prior to stopping the SG feedwater, verify that redundant means of cooling the RCS to cold shutdown conditions are OPERABLE. If redundant means are not OPERABLE, suspend LCO 3.0.3 and all other LCO Required Actions requiring MODE changes until redundant means are restored to OPERABLE status.

Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Turkey Point Unit 7 3.5.4 - 2

Technical Specifications PRHR HX - Operating 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify the outlet manual isolation valve is fully open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.4.2 Verify the inlet motor operated isolation valve is open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.4.3 Verify the volume of noncondensible gases in the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months PRHR HX inlet line has not caused the high-point water level to drop below the sensor.

SR 3.5.4.4 Verify that power is removed from the inlet motor 31 days operated isolation valve.

SR 3.5.4.5 Verify both PRHR air operated outlet isolation valves In accordance with and both IRWST gutter isolation valves are the Inservice OPERABLE by stroking open the valves. Testing Program SR 3.5.4.6 Verify PRHR HX heat transfer performance in 10 years accordance with the System Level OPERABILITY Testing Program.

SR 3.5.4.7 Verify by visual inspection that the IRWST gutter and 24 months downspout screens are not restricted by debris.

Turkey Point Unit 7 3.5.4 - 3

Technical Specifications PRHR HX - Shutdown, RCS Intact 3.5.5 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.5 Passive Residual Heat Removal Heat Exchanger (PRHR HX) - Shutdown, Reactor Coolant System (RCS) Intact LCO 3.5.5 The PRHR HX shall be OPERABLE.

- NOTE -

When any reactor coolant pumps (RCPs) are operating, at least one RCP must be operating in the loop with the PRHR HX, Loop 1.

APPLICABILITY: MODE 4 with the RCS cooling provided by the Normal Residual Heat Removal System (RNS).

MODE 5 with the RCS pressure boundary intact and pressurizer level 20%.

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

B. One air operated In- B.1 Restore air operated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Containment Refueling IRWST gutter isolation Water Storage Tank valve to OPERABLE (IRWST) gutter isolation status.

valve inoperable.

C. Presence of non- C.1 Vent noncondensible 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months condensible gases in gases.

the high point vent.

D. PRHR HX inoperable D.1 Restore PRHR HX to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for reasons other than OPERABLE status.

Condition A, B, or C.

Turkey Point Unit 7 3.5.5 - 1

Technical Specifications PRHR HX - Shutdown, RCS Intact 3.5.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Initiate action to be in Immediately associated Completion MODE 5 with the RCS Time not met. pressure boundary open and > 20% pressurizer OR level.

LCO not met for reasons other than A, B, C, or D.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 The SRs of Specification 3.5.4, Passive Residual In accordance with Heat Removal Heat Exchanger (PRHR HX) - applicable SRs Operating - are applicable.

Turkey Point Unit 7 3.5.5 - 2

Technical Specifications IRWST - Operating 3.5.6 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.6 In-containment Refueling Water Storage Tank (IRWST) - Operating LCO 3.5.6 The IRWST, with two injection flow paths and two containment recirculation flow paths, shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One IRWST injection A.1 Restore the inoperable 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months line actuation valve flow actuation valve flow path to path inoperable. OPERABLE status.

OR One containment recirculation line actuation valve flow path inoperable.

B. One IRWST injection B.1 Vent noncondensible 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months line inoperable due to gases.

presence of noncondensible gases in one high point vent.

C. One IRWST injection C.1 Vent noncondensible 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months line inoperable due to gases from one high point presence of vent.

noncondensible gases in both high point vents.

D. IRWST boron D.1 Restore IRWST to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months concentration not within OPERABLE status.

limits.

OR IRWST borated water temperature not within limits.

OR Turkey Point Unit 7 3.5.6 - 1

Technical Specifications IRWST - Operating 3.5.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME IRWST borated water volume < 100% and

> 97% of limit.

E. One motor operated E.1 Restore motor operated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months IRWST isolation valve IRWST isolation valve to not fully open. fully open condition with power removed from both OR valves.

Power is not removed from one or more motor operated IRWST isolation valves.

F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months LCO not met for reasons other than Condition A, B, C, D, or E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Verify the IRWST water temperature is < 120°F. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.5.6.2 Verify the IRWST borated water volume is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> 73,100 cu. ft.

SR 3.5.6.3 Verify the volume of noncondensible gases in each of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the four IRWST injection squib valve outlet line pipe stubs has not caused the high-point water level to drop below the sensor.

Turkey Point Unit 7 3.5.6 - 2

Technical Specifications IRWST - Operating 3.5.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.6.4 Verify the IRWST boron concentration is 2600 ppm 31 days and 2900 ppm.

AND Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of 15,000 gal SR 3.5.6.5 Verify each motor operated IRWST isolation valve is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months fully open.

SR 3.5.6.6 Verify power is removed from each motor operated 31 days IRWST isolation valve.

SR 3.5.6.7 Verify each motor operated containment recirculation 31 days isolation valve is fully open.

SR 3.5.6.8 Verify each IRWST injection and containment In accordance with recirculation squib valve is OPERABLE in accordance the Inservice with the Inservice Testing Program. Testing Program SR 3.5.6.9 Verify by visual inspection that the IRWST screens 24 months and the containment recirculation screens are not restricted by debris.

SR 3.5.6.10 Verify IRWST injection and recirculation system flow 10 years performance in accordance with the System Level OPERABILITY Testing Program.

Turkey Point Unit 7 3.5.6 - 3

Technical Specifications IRWST - Shutdown, MODE 5 3.5.7 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.7 In-containment Refueling Water Storage Tank (IRWST) - Shutdown, MODE 5 LCO 3.5.7 The IRWST, with one injection flow path and one containment recirculation flow path, shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required motor A.1 Open required motor 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months operated containment operated containment recirculation isolation recirculation isolation valve not fully open. valve.

B. Required IRWST B.1 Vent noncondensible 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months injection line inoperable gases.

due to presence of noncondensible gases in one high point vent.

C. Required IRWST C.1 Vent noncondensible 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months injection line inoperable gases from one high point due to presence of vent.

noncondensible gases in both high point vents.

D. IRWST boron D.1 Restore IRWST to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months concentration not within OPERABLE status.

limits.

OR IRWST borated water temperature not within limits.

OR IRWST borated water volume < 100% and

> 97% of limit.

Turkey Point Unit 7 3.5.7 - 1

Technical Specifications IRWST - Shutdown, MODE 5 3.5.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required motor E.1 Restore required motor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months operated IRWST operated IRWST isolation isolation valve not fully valve to fully open open. condition with power removed.

OR Power is not removed from required motor operated IRWST isolation valve.

F. Required Action and F.1 Initiate action to be in Immediately associated Completion MODE 5 with the Reactor Time not met. Coolant System (RCS) pressure boundary intact OR and 20% pressurizer level.

LCO not met for AND reasons other than F.2 Suspend positive reactivity Immediately Condition A, B, C, D, or additions.

E.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.7.1 For the IRWST and flow paths required to be In accordance with OPERABLE, the SRs of Specification 3.5.6, applicable SRs In-containment Refueling Water Storage Tank (IRWST) - Operating, are applicable.

Turkey Point Unit 7 3.5.7 - 2

Technical Specifications IRWST - Shutdown, MODE 6 3.5.8 3.5 PASSIVE CORE COOLING SYSTEM (PXS) 3.5.8 In-containment Refueling Water Storage Tank (IRWST) - Shutdown, MODE 6 LCO 3.5.8 The IRWST, with one injection flow path and one containment recirculation flow path, shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required motor A.1 Open required motor 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months operated containment operated containment recirculation isolation recirculation isolation valve not fully open. valve.

B. Required IRWST B.1 Vent noncondensible 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months injection line inoperable gases.

due to presence of noncondensible gases in one high point vent.

C. Required IRWST C.1 Vent noncondensible 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months injection line inoperable gases from one high point due to presence of vent.

noncondensible gases in both high point vents.

D. IRWST and refueling D.1 Restore IRWST to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months cavity boron concentra- OPERABLE status.

tion not within limits.

OR IRWST and refueling cavity borated water temperature not within limits.

OR IRWST and refueling cavity borated water volume < 100% and

> 97% of limit.

Turkey Point Unit 7 3.5.8 - 1

Technical Specifications IRWST - Shutdown, MODE 6 3.5.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required motor E.1 Restore required motor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months operated IRWST operated IRWST isolation isolation valve not fully valve to fully open open. condition with power removed.

OR Power is not removed from required motor operated IRWST isolation valve.

F. Required Action and F.1 Initiate action to be in Immediately associated Completion MODE 6 with the water Time not met. level 23 feet above the top of the reactor vessel OR flange.

LCO not met for AND reasons other than Condition A, B, C, D, or F.2 Suspend positive reactivity Immediately E. additions.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.8.1 Verify the IRWST and refueling cavity water 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months temperature is < 120°F.

SR 3.5.8.2 Verify the IRWST and refueling cavity water total 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months borated water volume is > 73,100 cu. ft.

SR 3.5.8.3 Verify the IRWST and refueling cavity boron 31 days concentration is 2600 ppm and 2900 ppm.

AND Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of 15,000 gal Turkey Point Unit 7 3.5.8 - 2

Technical Specifications IRWST - Shutdown, MODE 6 3.5.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.8.4 For the IRWST and flow paths required to be In accordance with OPERABLE, the following SRs of Specification 3.5.6, applicable SRs In-containment Refueling Water Storage Tank (IRWST) - Operating are applicable:

SR 3.5.6.3 SR 3.5.6.6 SR 3.5.6.8 SR 3.5.6.10 SR 3.5.6.5 SR 3.5.6.7 SR 3.5.6.9 Turkey Point Unit 7 3.5.8 - 3

Technical Specifications Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment A.1 Restore containment to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE status.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and leakage- In accordance with rate testing except for containment air-lock testing, in the Containment accordance with the Containment Leakage Rate Leakage Rate Testing Program. Testing Program Turkey Point Unit 7 3.6.1 - 1

Technical Specifications Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

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

ACTIONS

- NOTES -

1. Entry and exit is permissible to perform repairs on the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1, Containment, when air lock leakage results in exceeding the overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more ---------------------------------------------

containment air locks - NOTES -

with one containment 1. Required Actions A.1, A.2, air lock door inoperable. and A.3 are not applicable if both doors in the same air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls if both air locks are inoperable.

A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

AND Turkey Point Unit 7 3.6.2 - 1

Technical Specifications Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 Lock the OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected air lock.

AND A.3 ------------------------------------

- NOTE -

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock.

B. One or more ------------------------------------

containment air locks - NOTES -

with containment air 1. Required Actions B.1, B.2, lock interlock and B.3 are not applicable if mechanism inoperable. both doors in the same air lock are inoperable and Condition C is entered.

2. Entry and exit of containment is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE door 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is closed in the affected air lock.

AND Turkey Point Unit 7 3.6.2 - 2

Technical Specifications Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected air lock.

AND B.3 ------------------------------------

- NOTE -

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify an OPERABLE door Once per 31 days is locked closed in the affected air lock.

C. One or more C.1 Initiate action to evaluate Immediately containment air locks overall containment inoperable for reasons leakage rate per other than Condition A LCO 3.6.1.

or B.

AND C.2 Verify a door is closed in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the affected air lock.

AND C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Turkey Point Unit 7 3.6.2 - 3

Technical Specifications Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 -----------------------------------------------------------------------

- NOTES -

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

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

Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rate the Containment Testing Program. Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at a 24 months time.

Turkey Point Unit 7 3.6.2 - 4

Technical Specifications Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.

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

ACTIONS

- NOTES -

1. Penetration flow path(s) may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1, Containment, when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. -------------------------------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

- NOTE - penetration flow path by Only applicable to use of at least one closed penetration flow paths and de-activated automatic with two containment valve, closed manual isolation valves. valve, blind flange, or

check valve with flow through the valve secured.

One or more penetration flow paths AND with one containment isolation valve inoperable.

Turkey Point Unit 7 3.6.3 - 1

Technical Specifications Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 ------------------------------------

- NOTES -

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means.

Verify the affected Once per 31 days for penetration flow path is isolation devices isolated. outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. -------------------------------- B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

- NOTE - penetration flow path by Only applicable to use of at least one closed penetration flow paths and de-activated automatic with two containment valve, closed manual isolation valves. valve, or blind flange.

One or more penetration flow paths with two containment isolation valves inoperable.

Turkey Point Unit 7 3.6.3 - 2

Technical Specifications Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -------------------------------- C.1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

- NOTE - penetration flow path by Only applicable to use of at least one closed penetration flow paths and de-activated automatic with only one valve, closed manual containment isolation valve, or blind flange.

valve and a closed system. AND C.2 ------------------------------------

One or more - NOTES -

penetration flow paths 1. Isolation devices in with one containment high radiation areas isolation valve may be verified by inoperable. use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means.

Verify that the affected Once per 31 days penetration flow path is isolated.

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

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Turkey Point Unit 7 3.6.3 - 3

Technical Specifications Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 16 inch containment purge valve is 31 days closed, except when the 16 inch containment purge valves are open for pressure control, ALARA or air quality considerations for personnel containment entry, or for Surveillances which require the valves to be open.

SR 3.6.3.2 -----------------------------------------------------------------------

- NOTE -

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

Verify each containment isolation manual valve and 31 days blind flange that is located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

SR 3.6.3.3 -----------------------------------------------------------------------

- NOTE -

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

Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment and not MODE 4 from locked, sealed, or otherwise secured and required to MODE 5 if not be closed during accident conditions is closed, except performed within for containment isolation valves that are open under the previous administrative controls. 92 days SR 3.6.3.4 Verify the isolation time of each automatic power In accordance with operated containment isolation valve is within limits. the Inservice Testing Program SR 3.6.3.5 Verify each automatic containment isolation valve that 24 months is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

Turkey Point Unit 7 3.6.3 - 4

Technical Specifications Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be -0.2 psig and +1.0 psig.

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

MODES 5 and 6 without an open containment air flow path 6 inches in diameter.

- NOTE -

The high pressure LCO limit is not applicable in MODES 5 or 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits. pressure to within limits.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months AND B.3 Open a containment air 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months flow path 6 inches in diameter.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.6.4 - 1

Technical Specifications Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be 120°F.

APPLICABILITY: MODES 1, 2, 3, and 4, MODES 5 and 6 with both containment equipment hatches and both containment airlocks closed.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average A.1 Restore containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months air temperature not average air temperature to within limit. within limit.

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

B.2 Be in MODE 5 or 6. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months AND B.3 Open containment 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months equipment hatch or containment airlock.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit.

Turkey Point Unit 7 3.6.5 - 1

Technical Specifications PCS - Operating 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Passive Containment Cooling System (PCS) - Operating LCO 3.6.6 The passive containment cooling system shall be OPERABLE, with all three water flow paths OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One passive A.1 Restore flow path to 7 days containment cooling OPERABLE status.

water flow path inoperable.

B. Two passive B.1 Restore flow paths to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months containment cooling OPERABLE status.

water flow paths inoperable.

C. One or more water C.1 Restore water storage tank 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months storage tank to OPERABLE status.

parameters (temperature and volume) not within limits.

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

D.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months OR LCO not met for reasons other than A, B, or C.

Turkey Point Unit 7 3.6.6 - 1

Technical Specifications PCS - Operating 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify the water storage tank temperature 40°F and 7 days 120°F.

AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when water storage tank temperature is verified 50°F or 100°F SR 3.6.6.2 Verify the water storage tank volume 756,700 7 days gallons.

SR 3.6.6.3 Verify each passive containment cooling system, 31 days power operated, and automatic valve in each flow path that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.6.6.4 Verify each passive containment cooling system 24 months automatic valve in each flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.5 Verify the air flow path from the shield building 24 months annulus inlet to the exit is unobstructed and, that all air baffle sections are in place.

SR 3.6.6.6 Verify passive containment cooling system flow and At first refueling water coverage performance in accordance with the System Level OPERABILITY Testing Program. AND 10 years Turkey Point Unit 7 3.6.6 - 2

Technical Specifications PCS - Shutdown 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Passive Containment Cooling System (PCS) - Shutdown LCO 3.6.7 The passive containment cooling system shall be OPERABLE with all three water flow paths OPERABLE.

APPLICABILITY: MODE 5 with the calculated reactor decay heat > 6.0 MWt, MODE 6 with the calculated reactor decay heat > 6.0 MWt.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One passive A.1 Restore flow path to 7 days containment cooling OPERABLE status.

water flow path inoperable.

B. Two passive B.1 Restore flow paths to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months containment cooling OPERABLE status.

water flow paths inoperable.

C. One or more water C.1 Restore water storage tank 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months storage tank to OPERABLE status.

parameters (temperature and volume) not within limits.

Turkey Point Unit 7 3.6.7 - 1

Technical Specifications PCS - Shutdown 3.6.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action D.1.1 If in MODE 5, initiate Immediately and associated action to be in MODE 5 Completion Time not with the Reactor Coolant met. System (RCS) pressure boundary intact and OR 20% pressurizer level.

LCO not met for OR reasons other than Condition A, B, or C. D.1.2 If in MODE 6, initiate Immediately action to be in MODE 6 with the water level 23 feet above the top of the reactor vessel flange.

AND D.2 Suspend positive reactivity Immediately additions.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 The SRs of Specification 3.6.6, Passive Containment In accordance with Cooling System - Operating, are applicable. applicable SRs Turkey Point Unit 7 3.6.7 - 2

Technical Specifications Containment Penetrations 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Containment Penetrations LCO 3.6.8 The containment penetrations shall be in the following status:

a. The equipment hatches closed and held in place by four bolts or, if open, clear of obstructions such that the hatches can be closed prior to steaming into the containment.

b. One door in each air lock closed or, if open, the containment air locks shall be clear of obstructions such that they can be closed prior to steaming into the containment.

c. The containment spare penetrations, if open, shall be clear of obstructions such that the penetrations can be closed prior to steaming into the containment.

d. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. capable of being closed by an OPERABLE Containment Isolation signal.

APPLICABILITY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months containment penetrations to required penetrations not in status.

required status.

Turkey Point Unit 7 3.6.8 - 1

Technical Specifications Containment Penetrations 3.6.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action B.1.1 If in MODE 5, initiate Immediately and associated action to be in MODE 5 Completion Time not with the Reactor Coolant met. System (RCS) pressure boundary intact and 20%

OR pressurizer level.

LCO not met for OR reasons other than Condition A. B.1.2 If in MODE 6, initiate Immediately action to be in MODE 6 with the water level 23 feet above the top of the reactor vessel flange.

AND B.2 Suspend positive reactivity Immediately additions.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Verify each required containment penetration is in the 7 days required status.

SR 3.6.8.2 -----------------------------------------------------------------------

- NOTE -

Only required to be met for an open equipment hatch.

Verify that the hardware, tools, equipment and power Prior to hatch source necessary to install the equipment hatch are removal available.

AND 7 days Turkey Point Unit 7 3.6.8 - 2

Technical Specifications Containment Penetrations 3.6.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.8.3 -----------------------------------------------------------------------

- NOTE -

Not required to be met for automatic isolation valve(s) in penetrations closed to comply with LCO 3.6.8.d.1.

Verify one automatic isolation valve in each open 24 months penetration providing direct access from the containment atmosphere to the outside atmosphere actuates to the isolation position on an actual or simulated actuation signal.

Turkey Point Unit 7 3.6.8 - 3

Technical Specifications pH Adjustment 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 pH Adjustment LCO 3.6.9 The pH adjustment baskets shall contain 560 ft3 of trisodium phosphate (TSP).

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. The volume of trisodium A.1 Restore volume of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months phosphate not within trisodium phosphate to limit. within limit.

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

B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Verify that the pH adjustment baskets contain at least 24 months 560 ft3 of TSP (Na3PO4-12 H2O).

SR 3.6.9.2 Verify that a sample from the pH adjustment baskets 24 months provides adequate pH adjustment of the post-accident water.

Turkey Point Unit 7 3.6.9 - 1

Technical Specifications Vacuum Relief Valves 3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Vacuum Relief Valves LCO 3.6.10 Two vacuum relief flow paths shall be OPERABLE.

AND Containment inside to outside differential air temperature shall be 90°F.

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

MODES 5 and 6 without an open containment air flow path 6 inches in diameter.

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

B. Containment inside to B.1 Restore containment inside 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months outside differential air to outside differential air temperature > 90°F. temperature to within limit.

OR B.2 Reduce containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months average temperature 80°F.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND Conditions A or B not met. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR AND Both vacuum relief C.3 Open a containment air 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months flow paths inoperable. flow path 6 inches in diameter.

Turkey Point Unit 7 3.6.10 - 1

Technical Specifications Vacuum Relief Valves 3.6.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Verify containment inside to outside differential air 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months temperature is 90°F.

SR 3.6.10.2 Verify each vacuum relief flow path is OPERABLE In accordance in accordance with the Inservice Testing Program. with the Inservice Testing Program Turkey Point Unit 7 3.6.10 - 2

Technical Specifications MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)

LCO 3.7.1 The MSSVs shall be OPERABLE as specified in Table 3.7.1-1 and Table 3.7.1-2.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with the Reactor Coolant System (RCS) not being cooled by the Normal Residual Heat Removal System (RNS).

ACTIONS

- NOTE -

Separate Condition entry is allowed for each MSSV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months MSSVs inoperable. POWER to less than or equal to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

AND A.2 ------------------------------------

- NOTE -

Only required in MODE 1.

Reduce the Power Range 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months 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.

Turkey Point Unit 7 3.7.1 - 1

Technical Specifications MSSVs 3.7.1 ACTIONS (continued)

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

B.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR RCS cooling provided by the RNS.

One or more steam generators with

> 5 MSSVs inoperable.

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 In accordance with Table 3.7.1-2 in accordance with the Inservice Testing the Inservice Program. Following testing, lift settings shall be Testing Program within +/-1%.

Turkey Point Unit 7 3.7.1 - 2

Technical Specifications MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)

OPERABLE MSSVs versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs PER STEAM MAXIMUM ALLOWABLE GENERATOR POWER (% RTP) 5 60 4 46 3 32 2 18 Turkey Point Unit 7 3.7.1 - 3

Technical Specifications MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)

Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING STEAM GENERATOR (psig + 1%)

1 #2 V030A V030B 1185 V031A V031B 1197 V032A V032B 1209 V033A V033B 1221 V034A V034B 1232 V035A V035B 1232 Turkey Point Unit 7 3.7.1 - 4

Technical Specifications MSIVs 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs)

LCO 3.7.2 The minimum combination of valves required for steam flow isolation shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2, 3, and 4 except when steam flow is isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIV inoperable in A. Restore valve to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months MODE 1. OPERABLE status.

B. One or more of the B. Restore valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months turbine stop valves and OPERABLE status.

its associated turbine control valve, turbine bypass valves, or moisture separator reheater 2nd stage steam isolation valves inoperable in MODE 1.

Turkey Point Unit 7 3.7.2 - 1

Technical Specifications MSIVs 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two MSIVs inoperable C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in MODE 1.

OR One MSIV inoperable and one or more of the turbine stop valves and its associated turbine control valve, all turbine bypass valves, or moisture separator reheater 2nd stage steam isolation valves inoperable in MODE 1.

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

Turkey Point Unit 7 3.7.2 - 2

Technical Specifications MSIVs 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. -------------------------------- D.1 Isolate associated steam 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

- NOTE - flow path.

Separate Condition entry is allowed for each AND MSIV.

D.2 Verify flow path remains Once per 7 days closed.

One or two MSIVs inoperable in MODE 2, 3, or 4.

OR One or more of the turbine stop valves and its associated turbine control valve, all turbine bypass valves, or moisture separator reheater 2nd stage steam isolation valves inoperable in MODE 2, 3, or 4.

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

E.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Reactor Coolant System (RCS) cooling provided by the Normal Residual Heat Removal System (RNS).

Turkey Point Unit 7 3.7.2 - 3

Technical Specifications MSIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -----------------------------------------------------------------------

- NOTE -

Only required to be performed prior to entry into MODE 2.

Verify MSIV closure time 5 seconds on an actual or In accordance with simulated actuation signal. the Inservice Testing Program SR 3.7.2.2 -----------------------------------------------------------------------

- NOTE -

Only required to be performed prior to entry into MODE 2.

Verify turbine stop, turbine control, turbine bypass, In accordance with and moisture separator reheater 2nd stage steam the Inservice isolation valves closure time 5 seconds on an Testing Program actual or simulated actuation signal.

Turkey Point Unit 7 3.7.2 - 4

Technical Specifications MFIVs and MFCVs 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation and Control Valves (MFIVs and MFCVs)

LCO 3.7.3 The MFIV and the MFCV for each Steam Generator shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 except when the MFIVs or associated MFCV are closed and deactivated.

ACTIONS

- NOTE -

Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two MFIVs A.1 Close or isolate the MFIV 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. flow path.

AND A.2 Verify MFIV is closed or Once per 7 days isolated.

B. One or two MFCVs B.1 Close or isolate the MFCV 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. the flow path.

AND B.2 Verify MFCV is closed or Once per 7 days isolated.

C. Two valves in the same C.1 Isolate affected flow path. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flow path inoperable.

Turkey Point Unit 7 3.7.3 - 1

Technical Specifications MFIVs and MFCVs 3.7.3 ACTIONS (continued)

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

D.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Reactor Coolant System (RCS) cooling provided by the Normal Residual Heat Removal System (RNS).

AND D.3.1 Isolate the affected flow 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months path(s).

OR D.3.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 -----------------------------------------------------------------------

- NOTE -

Only required to be performed prior to entry into MODE 2.

Verify the closure time of each MFIV and MFCV is In accordance with 5 seconds on an actual or simulated actuation the Inservice signal. Testing Program Turkey Point Unit 7 3.7.3 - 2

Technical Specifications Secondary Specific Activity 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Secondary Specific Activity LCO 3.7.4 The specific activity of the secondary coolant shall be < 0.01 Ci/gm DOSE EQUIVALENT I-131.

APPLICABILITY: MODES 1, 2, 3 and 4.

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

AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify the specific activity of the secondary coolant 31 days 0.01 Ci/gm DOSE EQUIVALENT I-131.

Turkey Point Unit 7 3.7.4 - 1

Technical Specifications Spent Fuel Pool Water Level 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Spent Fuel Pool Water Level LCO 3.7.5 The spent fuel pool water level shall be 23 ft above the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: At all times.

ACTIONS

- NOTE -

LCOs 3.0.3 and 3.0.8 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pool water A.1 Suspend movement of Immediately level < 23 ft. irradiated fuel assemblies in the spent fuel pool.

AND A.2 Initiate action to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months water level to 23 ft.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify the spent fuel pool water level is 23 ft above 7 days the top of the irradiated fuel assemblies seated in the storage racks.

Turkey Point Unit 7 3.7.5 - 1

Technical Specifications VES 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Control Room Emergency Habitability System (VES)

LCO 3.7.6 The VES shall be OPERABLE.

- NOTE -

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

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

ACTIONS

- NOTE -

LCO 3.0.8 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One valve or damper A.1 Restore valve or damper to 7 days inoperable. OPERABLE status.

B. One PMS division B.1 Restore MCR Load-shed 7 days inoperable in MCR panel(s) to OPERABLE Load-Shed Panel(s). status.

C. MCRE air temperature C.1 Restore MCRE air 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months not within limit. temperature to within limit.

D. Air temperature in one D.1 Restore air temperature of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or more required rooms required room(s) to within not within limit. limit.

E. VES inoperable due to E.1 Initiate action to implement Immediately inoperable MCRE mitigating actions.

boundary in MODE 1, 2, 3, or 4.

Turkey Point Unit 7 3.7.6 - 1

Technical Specifications VES 3.7.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME AND E.2 Verify mitigating actions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensure MCRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND E.3 Restore MCRE boundary 90 days to OPERABLE status.

F. One bank of VES air F.1 Verify that the OPERABLE 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months tanks (8 tanks) tanks contain greater than inoperable. 245,680 scf of compressed AND air.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND F.2 Verify VBS MCRE ancillary 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months fans and supporting equipment are available.

AND F.3 Restore VES to 7 days OPERABLE status.

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

OR VES inoperable for reasons other than Conditions A, B, C, or D, E or F in MODE 1, 2, 3, or 4.

Turkey Point Unit 7 3.7.6 - 2

Technical Specifications VES 3.7.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action H.1 Suspend movement of Immediately and associated irradiated fuel assemblies.

Completion Time of Conditions A, B, C, D, E or F not met during movement of irradiated fuel.

OR VES inoperable for reasons other than Conditions A, B, C, D, E or F during movement of irradiated fuel.

OR VES inoperable due to inoperable MCRE boundary during movement of irradiated fuel.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify MCRE air temperature is 75°F. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.7.6.2 Verify that the compressed air storage tanks contain 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months greater than 327,574 scf of compressed air.

SR 3.7.6.3 Verify the air temperatures of required rooms are 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 85°F.

SR 3.7.6.4 Operate VES for 15 minutes. 31 days SR 3.7.6.5 Verify that each VES air header manual isolation 31 days valve is in an open position.

Turkey Point Unit 7 3.7.6 - 3

Technical Specifications VES 3.7.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.6.6 Verify that the air quality of the air storage tanks 92 days meets the requirements of Appendix C, Table C-1 of ASHRAE Standard 62 with a pressure dew point of 40°F or lower at 3400 psig or greater.

SR 3.7.6.7 Verify that each VES air delivery isolation valve is In accordance with OPERABLE. the Inservice Testing Program SR 3.7.6.8 Verify that each VES pressure relief isolation valve In accordance with within the MCRE pressure boundary is OPERABLE. the Inservice Testing Program SR 3.7.6.9 Verify that the self-contained pressure regulating In accordance with valve in each VES air delivery flow path is the Inservice OPERABLE. Testing Program SR 3.7.6.10 Perform required MCRE unfiltered air inleakage In accordance with testing in accordance with the Main Control Room the Main Control Envelope Habitability Program. Room Envelope Habitability Program SR 3.7.6.11 Perform required VES Passive Filtration system filter In accordance with testing in accordance with the Ventilation Filter the VFTP Testing Program (VFTP).

SR 3.7.6.12 Verify the MCR load-shed function actuates upon 24 months receipt of an actual or simulated actuation signal.

SR 3.7.6.13 Verify that all MCRE isolation valves are OPERABLE 24 months and will close upon receipt of an actual or simulated actuation signal.

SR 3.7.6.14 Verify that each VES pressure relief damper is 24 months OPERABLE.

Turkey Point Unit 7 3.7.6 - 4

Technical Specifications Startup Feedwater Isolation and Control Valves 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Startup Feedwater Isolation and Control Valves LCO 3.7.7 Both Startup Feedwater Isolation Valves and Control Valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 except when the startup feedwater flow paths are isolated.

ACTIONS

- NOTES -

1. Flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each flow path.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths A.1 Isolate the affected flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months with one inoperable path(s).

valve.

AND A.2 Verify affected flow path(s) Once per 7 days is isolated.

B. One flow path with two B.1 Isolate the affected flow 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable valves. path.

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

C.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Reactor Coolant System (RCS) cooling provided by the Normal Residual Heat Removal System (RNS).

AND C.3 Isolate the affected flow 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months path(s).

Turkey Point Unit 7 3.7.7 - 1

Technical Specifications Startup Feedwater Isolation and Control Valves 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify both startup feedwater isolation and control In accordance with valves are OPERABLE. the Inservice Testing Program Turkey Point Unit 7 3.7.7 - 2

Technical Specifications Main Steam Line Leakage 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Main Steam Line Leakage LCO 3.7.8 Main Steam Line leakage through the pipe walls inside containment shall be limited to 0.5 gpm.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Main Steam Line A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months leakage exceeds operational limit. AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify main steam line leakage into the containment Per SR 3.4.7.1 sump 0.5 gpm.

Turkey Point Unit 7 3.7.8 - 1

Technical Specifications Fuel Storage Pool Makeup Water Sources 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Fuel Storage Pool Makeup Water Sources LCO 3.7.9 Fuel storage pool makeup water sources shall be OPERABLE.

- NOTES -

1. OPERABILITY of the cask washdown pit is required when the calculated spent fuel storage pool decay heat > 4.7 MWt and 7.2 MWt.

2. OPERABILITY of the cask loading pit is required when the calculated spent fuel storage pool decay heat > 5.6 MWt and 7.2 MWt.

3. OPERABILITY of the Passive Containment Cooling Water Storage Tank (PCCWST) is required as a spent fuel storage pool makeup water source when the calculated spent fuel storage pool decay heat

> 7.2 MWt. If the reactor decay heat is > 6.0 MWt, the PCCWST must be exclusively available for containment cooling in accordance with LCO 3.6.7.

APPLICABILITY: During storage of fuel in the spent fuel storage pool with a calculated decay heat > 4.7 MWt.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 ------------------------------------

spent fuel storage pool - NOTE -

makeup water sources LCOs 3.0.3 and 3.0.8 are inoperable. not applicable.

Initiate action to restore the Immediately required makeup water source(s) to OPERABLE status.

Turkey Point Unit 7 3.7.9 - 1

Technical Specifications Fuel Storage Pool Makeup Water Sources 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 -----------------------------------------------------------------------

- NOTE -

Only required to be performed when spent fuel storage pool calculated decay heat is > 7.2 MWt.

Verify one passive containment cooling system, 7 days motor-operated valve in each flow path is closed and locked, sealed, or otherwise secured in position.

SR 3.7.9.2 -----------------------------------------------------------------------

- NOTE -

Only required to be performed when spent fuel storage pool calculated decay heat is > 7.2 MWt.

Verify the PCCWST volume is 756,700 gallons. 7 days SR 3.7.9.3 -----------------------------------------------------------------------

- NOTE -

Only required to be performed when spent fuel storage pool calculated decay heat is 7.2 MWt.

Verify the water level in the cask washdown pit is 31 days 13.75 ft.

SR 3.7.9.4 -----------------------------------------------------------------------

- NOTE -

Only required to be performed when spent fuel storage pool calculated decay heat is > 5.6 MWt and 7.2 MWt.

Verify the water level in the cask loading pit is 31 days 43.9 ft. and in communication with the spent fuel storage pool.

Turkey Point Unit 7 3.7.9 - 2

Technical Specifications Fuel Storage Pool Makeup Water Sources 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.5 Verify the spent fuel storage pool makeup isolation In accordance with valves PCS-PL-V009, PCS-PL-V045, PCS-PL-V051, the Inservice SFS-PL-V042, SFS-PL-V045, SFS-PL-V049, Testing Program SFS- PL-V066, and SFS-PL-V068 are OPERABLE in accordance with the Inservice Testing Program.

Turkey Point Unit 7 3.7.9 - 3

Technical Specifications Steam Generator Isolation Valves 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Steam Generator (SG) Isolation Valves LCO 3.7.10 The steam generator isolation valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with the Reactor Coolant System (RCS) not being cooled by the Normal Residual Heat Removal System (RNS).

ACTIONS

- NOTES -

1. Steam generator blowdown flow path(s) may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each flow path.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORV flow A.1 Isolate the flow path by use 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months paths with one SG of at least one closed and isolation valve deactivated automatic inoperable. valve.

B. One or more blowdown B.1 Isolate the flow path by 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months flow paths with one SG one closed valve.

isolation valve inoperable. AND B.2 Verify that the affected SG Once per 7 days blowdown flow path is isolated.

C. One or more PORV flow C.1 Isolate the affected flow 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months paths with two SG path by use of at least one isolation valves closed and deactivated inoperable. automatic valve.

Turkey Point Unit 7 3.7.10 - 1

Technical Specifications Steam Generator Isolation Valves 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more blowdown D.1 Isolate the flow path by 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flow paths with two SG one closed valve.

isolation valves inoperable. AND D.2 Verify that the affected SG Once per 7 days blowdown flow path is isolated.

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

E.2 Be in MODE 4 with the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RCS cooling provided by the RNS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify each steam generator isolation valve (PORV In accordance with block valves (SGS-PL-V027A & B), PORVs the Inservice (SGS-PL-V233A & B), and blowdown isolation valves Testing Program (SGS-PL-V074A & B and SGS-PL-V075A & B)) is OPERABLE by stroking the valve closed.

Turkey Point Unit 7 3.7.10 - 2

Technical Specifications Fuel Storage Pool Boron Concentration 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Fuel Storage Pool Boron Concentration LCO 3.7.11 The fuel storage pool boron concentration shall be 2300 ppm.

APPLICABILITY: When fuel assemblies are stored in the fuel storage pool and a fuel storage pool verification has not been performed since the last movement of fuel assemblies in the fuel storage pool.

ACTIONS

- NOTE -

LCOs 3.0.3 and 3.0.8 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron A.1 Suspend movement of fuel Immediately concentration not within assemblies in the fuel limit. storage pool.

AND A.2.1 Initiate action to restore Immediately fuel storage pool boron concentration to within limit.

OR A.2.2 Initiate action to perform a Immediately fuel storage pool verification.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify the fuel storage pool boron concentration is 7 days within limit.

Turkey Point Unit 7 3.7.11 - 1

Technical Specifications Spent Fuel Pool Storage 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Spent Fuel Pool Storage LCO 3.7.12 The combination of initial enrichment and burnup of each fuel assembly stored in Region 2 shall be within the limits specified in Figure 3.7.12-1.

APPLICABILITY: Whenever any fuel assembly is stored in Region 2 of the spent fuel storage pool.

ACTIONS

- NOTE -

LCOs 3.0.3 and 3.0.8 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Initiate action to move the Immediately LCO not met. noncomplying fuel assembly to an acceptable storage location.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify by administrative means the initial enrichment Prior to storing the and burnup of the fuel assembly is in accordance with fuel assembly in Figure 3.7.12-1. Region 2 Turkey Point Unit 7 3.7.12 - 1

Technical Specifications Spent Fuel Pool Storage 3.7.12 Figure 3.7.12-1 Minimum Fuel Assembly Burnup Versus Initial Enrichment for Region 2 Spent Fuel Cells Turkey Point Unit 7 3.7.12 - 2

Technical Specifications DC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 DC Sources - Operating LCO 3.8.1 The Division A, B, C, and D Class 1E DC power subsystems shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more battery A.1 Restore battery terminal 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months chargers in one division voltage to greater than or inoperable. equal to the minimum established float voltage.

AND A.2 Verify battery float current Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 2 amps.

AND A.3 Restore battery charger(s) 7 days to OPERABLE status.

B. One or more battery B.1 Restore battery terminal 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months chargers in two voltage to greater than or divisions inoperable. equal to the minimum established float voltage.

AND B.2 Verify battery float current Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 2 amps.

AND B.3 Restore battery charger(s) 7 days to OPERABLE status.

Turkey Point Unit 7 3.8.1 - 1

Technical Specifications DC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more batteries in C.1 Restore batteries to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months one division inoperable. OPERABLE status.

D. One or more batteries in D.1 Restore batteries to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months two divisions OPERABLE status.

inoperable.

E. One DC electrical E.1 Restore DC electrical 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months power subsystem power subsystem to inoperable for reasons OPERABLE status.

other than Condition A or C.

F. Two DC electrical power F.1 Restore DC electrical 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months subsystems inoperable power subsystem to for reasons other than B OPERABLE status.

or D.

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

G.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify battery terminal voltage is greater than or equal 7 days to the minimum established float voltage.

Turkey Point Unit 7 3.8.1 - 2

Technical Specifications DC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.2 Verify each battery charger supplies 200 amps at 24 months greater than or equal to the minimum established float voltage for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

OR Verify each 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.

SR 3.8.1.3 -----------------------------------------------------------------------

- NOTES -

1. The modified performance discharge test in SR 3.8.7.6 may be performed in lieu of SR 3.8.1.3.

2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4 unless the spare battery is connected to replace the battery being tested. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify battery capacity is adequate to supply, and 24 months maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

Turkey Point Unit 7 3.8.1 - 3

Technical Specifications DC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 DC Sources - Shutdown LCO 3.8.2 DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.6, Distribution Systems - Shutdown.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

- NOTE -

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected required Immediately DC electrical power features inoperable.

subsystems inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Suspend operations with a Immediately potential for draining the reactor vessel.

AND Turkey Point Unit 7 3.8.2 - 1

Technical Specifications DC Sources - Shutdown 3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.4 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.2.5 Initiate action to restore Immediately required DC electrical power subsystems to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 -----------------------------------------------------------------------

- NOTE -

The following SRs are not required to be performed:

SR 3.8.1.2 and SR 3.8.1.3.

For DC sources required to be OPERABLE, the In accordance with following SRs are applicable: applicable SRs SR 3.8.1.1 SR 3.8.1.2 SR 3.8.1.3 Turkey Point Unit 7 3.8.2 - 2

Technical Specifications Inverters - Operating 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Inverters - Operating LCO 3.8.3 The Division A, B, C, and D inverters (Divisions A and D, one each and Divisions B and C two each; six total) shall be OPERABLE.

- NOTES -

One inverter may be disconnected from its associated DC bus for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to perform an equalizing charge on its associated battery, providing:

1. The associated instrument and control bus is energized from its Class 1E constant voltage source transformer; and

2. All other AC instrument and control buses are energized from their associated OPERABLE inverters.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One inverter inoperable. A.1 ------------------------------------

- NOTE -

Enter applicable Conditions and Required Actions of LCO 3.8.5 Distribution Systems -

Operating with any instrument and control bus de-energized.

Restore inverter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Turkey Point Unit 7 3.8.3 - 1

Technical Specifications Inverters - Operating 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify correct inverter voltage, frequency, and 7 days alignment to required AC instrument and control buses.

Turkey Point Unit 7 3.8.3 - 2

Technical Specifications Inverters - Shutdown 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 Inverters - Shutdown LCO 3.8.4 Inverters shall be OPERABLE to support the onsite Class 1E power distribution subsystems required by LCO 3.8.6, Distribution Systems -

Shutdown.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

- NOTE -

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Declare affected required Immediately required inverters features inoperable.

inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Suspend operations with a Immediately potential for draining the reactor vessel.

AND Turkey Point Unit 7 3.8.4 - 1

Technical Specifications Inverters - Shutdown 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.4 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.2.5 Initiate action to restore Immediately required inverters to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify correct inverter voltage, frequency, and 7 days alignments to required AC instrument and control buses.

Turkey Point Unit 7 3.8.4 - 2

Technical Specifications Distribution Systems

- Operating 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 Distribution Systems - Operating LCO 3.8.5 The Division A, B, C, and D AC instrument and control bus and DC electrical power distribution subsystems shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Division AC A.1 Restore AC instrument and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months instrument and control control bus to OPERABLE bus inoperable. status. AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery of failure to meet the LCO B. One Division DC B.1 Restore DC electrical 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months electrical power power distribution distribution subsystem subsystem to OPERABLE AND inoperable. status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery of failure to meet the LCO C. Two Divisions AC C.1 Restore AC instrument and 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months instrument and control control bus to OPERABLE bus inoperable. status. AND 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet the LCO.

D. Two Divisions DC D.1 Restore DC electrical 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power power distribution distribution subsystem subsystem to OPERABLE AND inoperable. status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet the LCO.

Turkey Point Unit 7 3.8.5 - 1

Technical Specifications Distribution Systems

- Operating 3.8.5 ACTIONS (continued)

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

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Two Divisions with F.1 Enter LCO 3.0.3. Immediately inoperable distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 Verify correct breaker and switch alignments and 7 days voltage to required DC and AC instrument and control bus electrical power distribution subsystems.

Turkey Point Unit 7 3.8.5 - 2

Technical Specifications Distribution Systems

- Shutdown 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Distribution Systems - Shutdown LCO 3.8.6 The necessary portions of DC and AC instrument and control bus electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

- NOTE -

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately DC or AC instrument supported required and control bus features inoperable.

electrical power distribution subsystems OR inoperable.

A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Initiate action to suspend Immediately operations with a potential for draining the reactor vessel.

AND Turkey Point Unit 7 3.8.6 - 1

Technical Specifications Distribution Systems

- Shutdown 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.4 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.2.5 Initiate actions to restore Immediately required DC and AC instrument and control bus electrical power distribution subsystems to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify correct breaker and switch alignments and 7 days voltage to required DC and AC instrument and control bus electrical power distribution subsystems.

Turkey Point Unit 7 3.8.6 - 2

Technical Specifications Battery Parameters 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Battery Parameters LCO 3.8.7 Battery Parameters for Division A, B, C, and D batteries shall be within limits.

APPLICABILITY: When associated DC electrical power sources are required to be OPERABLE.

ACTIONS

- NOTE -

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries in A.1 Perform SR 3.8.1.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months one division with one or more battery cells float AND voltage < 2.07 V.

A.2 Perform SR 3.8.7.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND A.3 Restore affected cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months voltage 2.07 V.

B. One or more batteries in B.1 Perform SR 3.8.1.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months one division with float current > 2 amps. AND B.2 Restore battery float 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months current to 2 amps.

Turkey Point Unit 7 3.8.7 - 1

Technical Specifications Battery Parameters 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

- NOTE - - NOTE -

Required Action C.2 shall Required Actions C.1 and C.2 are be completed if electrolyte only applicable if electrolyte level level was below the top of was below the top of plates.

plates.

C. One or more batteries in C.1 Restore electrolyte level to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months one division with one or above top of plates.

more cells electrolyte level less than minimum AND established design limits. C.2 Verify no evidence of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months leakage.

AND C.3 Restore electrolyte level to 31 days greater than or equal to minimum established design limits.

D. One or more batteries in D.1 Restore battery pilot cell 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months one division with pilot temperature to greater cell electrolyte than or equal to minimum temperature less than established design limits.

minimum established design limits.

E. One or more batteries in E.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months two or more divisions parameters for batteries in with battery parameters three divisions to within not within limits. limits.

Turkey Point Unit 7 3.8.7 - 2

Technical Specifications Battery Parameters 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Declare associated battery Immediately associated Completion inoperable.

Time not met.

OR One or more batteries in one division with one or more battery cells float voltage < 2.07 V and float current > 2 amps.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 -----------------------------------------------------------------------

- NOTE -

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.1.1.

Verify each battery float current is 2 amps. 7 days SR 3.8.7.2 Verify each battery pilot cell voltage is 2.07 V. 31 days SR 3.8.7.3 Verify each battery connected cell electrolyte level is 31 days greater than or equal to minimum established design limits.

SR 3.8.7.4 Verify each battery pilot cell temperature is greater 31 days than or equal to minimum established design limits.

SR 3.8.7.5 Verify each battery connected cell voltage is 2.07 V. 92 days Turkey Point Unit 7 3.8.7 - 3

Technical Specifications Battery Parameters 3.8.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.7.6 -----------------------------------------------------------------------

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

Verify battery capacity is 80% of the manufacturers 60 months rating when subjected to a performance discharge test or a modified performance discharge test. 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 Turkey Point Unit 7 3.8.7 - 4

Technical Specifications Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentration of the Reactor Coolant System (RCS), the fuel transfer canal, and the refueling cavity shall be maintained within the limit specified in COLR.

APPLICABILITY: MODE 6.

- NOTE -

Only applicable to the fuel transfer canal and the refueling cavity when connected to the RCS.

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

AND A.2 Suspend positive reactivity Immediately additions.

AND A.3 Initiate actions to restore Immediately boron concentration to within limits.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in the COLR.

Turkey Point Unit 7 3.9.1 - 1

Technical Specifications Unborated Water Source Flow Paths 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Flow Paths LCO 3.9.2 Each unborated water source flow path shall be isolated.

APPLICABILITY: MODE 6.

ACTIONS

- NOTE -

Separate condition entry is allowed for each unborated water source flow path.

CONDITION REQUIRED ACTION COMPLETION TIME A. -------------------------------- A.1 Suspend CORE Immediately

- NOTE - ALTERATIONS.

Required Action A.3 must be completed AND whenever Condition A is entered. A.2 Initiate actions to isolate Immediately

flow paths.

One or more flow paths AND not isolated.

A.3 Perform SR 3.9.1.1. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each unborated water source flow path is 31 days isolated by at least one valve secured in the closed position.

Turkey Point Unit 7 3.9.2 - 1

Technical Specifications Nuclear Instrumentation 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Nuclear Instrumentation LCO 3.9.3 Two source range neutron flux monitors shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required source A.1 Suspend CORE Immediately range neutron flux ALTERATIONS.

monitor inoperable.

AND A.2 Suspend operations that Immediately would cause introduction into the Reactor Coolant System (RCS), coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

B. Two required source B.1 Initiate action to restore Immediately range neutron flux one source range neutron monitors inoperable. flux monitor to OPERABLE status.

AND B.2 Perform SR 3.9.1.1. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Turkey Point Unit 7 3.9.3 - 1

Technical Specifications Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.9.3.2 -----------------------------------------------------------------------

- NOTE-Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 24 months Turkey Point Unit 7 3.9.3 - 2

Technical Specifications Refueling Cavity Water Level 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Refueling Cavity Water Level LCO 3.9.4 Refueling Cavity Water Level shall be maintained 23 ft above the top of the reactor vessel flange.

APPLICABILITY: During movement of irradiated fuel assemblies within containment.

ACTIONS

- NOTE -

LCO 3.0.8 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.1 Suspend movement of Immediately level not within limit. irradiated fuel assemblies within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify that refueling cavity water level is 23 ft above 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the top of reactor vessel flange.

Turkey Point Unit 7 3.9.4 - 1

Technical Specifications Containment Penetrations 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Containment Penetrations LCO 3.9.5 The containment penetrations shall be in the following status:

a. The equipment hatches closed and held in place by four bolts or, if open, the containment air filtration system (VFS) shall be OPERABLE and operating;

b. One door in each air lock closed or, if open, the VFS shall be OPERABLE and operating;

c. The containment spare penetrations closed or, if open, the VFS shall be OPERABLE and operating;

d. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. Closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. Capable of being closed by an OPERABLE Containment Isolation signal.

- NOTE -

Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

APPLICABILITY: During movement of irradiated fuel assemblies within containment.

ACTIONS

- NOTE -

LCO 3.0.8 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Suspend movement of Immediately irradiated fuel assemblies within containment.

Turkey Point Unit 7 3.9.5 - 1

Technical Specifications Containment Penetrations 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify each required containment penetration is in the 7 days required status.

SR 3.9.5.2 -----------------------------------------------------------------------

- NOTE-Not required to be met for containment purge and exhaust valve(s) in penetrations closed to comply with LCO 3.9.5.d.1.

Verify each required containment purge and exhaust In accordance with valve actuates to the isolation position on a manual the Inservice Test actuation signal. Program SR 3.9.5.3 Verify the VFS can maintain a negative pressure 24 months

( -0.125 inches water gauge relative to outside atmospheric pressure) in the area enclosed by the containment and alternate barrier.

SR 3.9.5.4 Operate each VFS train for 10 continuous hours Within 31 days with the heaters operating. prior to fuel movement or CORE ALTERATIONS Turkey Point Unit 7 3.9.5 - 2

Technical Specifications VFS 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Containment Air Filtration System (VFS)

LCO 3.9.6 One VFS exhaust subsystem shall be OPERABLE.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel building.

ACTIONS

- NOTE -

LCOs 3.0.3 and 3.0.8 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Required VFS A.1 Suspend movement of Immediately exhaust subsystem irradiated fuel assemblies inoperable. in the fuel building.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Operate each VFS exhaust subsystem for Within 31 days

> 10 continuous hours with the heaters operating. prior to fuel movement SR 3.9.6.2 Verify the VAS fuel handling area subsystem aligns to 24 months the VFS exhaust subsystem on an actual or simulated actuation signal.

SR 3.9.6.3 Verify one VFS exhaust subsystem can maintain a 24 months negative pressure (< -0.125 inches water gauge relative to outside atmospheric pressure) in the fuel handling area.

Turkey Point Unit 7 3.9.6 - 1

Technical Specifications Decay Time 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Decay Time LCO 3.9.7 The reactor shall be subcritical for 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

APPLICABILITY: During movement of irradiated fuel in the reactor pressure vessel.

ACTIONS

- NOTE -

LCO 3.0.8 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor subcritical A.1 Suspend all operations Immediately

< 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . involving movement of irradiated fuel in the reactor pressure vessel.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify that the reactor has been subcritical for Prior to movement 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months by verification of the date and time of of irradiated fuel in subcriticality. the reactor vessel Turkey Point Unit 7 3.9.7 - 1

Technical Specifications Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site The site is approximately 25 miles south of Miami, 8 miles east of Florida City, and 9 miles southeast of Homestead, Florida.

4.1.1 Site and Exclusion Boundaries The Site Boundary is shown in Figure 4.1-1.

The Exclusion Area Boundary is shown in Figure 4.1-2.

4.1.2 Low Population Zone (LPZ)

The LPZ is defined by the 5 mile radius from the site center point as shown in Figure 4.1-1.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 157 fuel assemblies. Each assembly shall consist of a matrix of fuel rods clad with a zirconium based alloy and containing an initial composition of natural or slightly enriched uranium dioxide (UO2) as fuel material.

Limited substitutions of zirconium based 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 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 and Gray Rod Assemblies The reactor core shall contain 53 Rod Cluster Control Assemblies (RCCAs), each with 24 rodlets/RCCA. The RCCA absorber material shall be silver indium cadmium as approved by the NRC.

Additionally, there are 16 low worth Gray Rod Cluster Assemblies (GRCAs), with 24 rodlets/GRCA, which, in conjunction with the RCCAs, are used to augment MSHIM load follow operation.

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Technical Specifications Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 4.95 weight percent;

b. keff 0.95 if flooded with unborated water which includes an allowance for uncertainties (Region 1 racks);

c. A nominal 10.93 inch center-to-center distance between fuel assemblies placed in Region 1, a nominal 9.04 inch center-to-center distance between fuel assemblies placed in Region 2 of the spent fuel storage racks, and a nominal 11.65 inch center-to-center distance between fuel assemblies placed in the Defective Fuel Cells;

d. New or partially spent fuel assemblies with any discharge burnup may be allowed unrestricted storage in Region 1 and the Defective Fuel Cells of Figure 4.3-1;

e. Partially spent fuel assemblies meeting the initial enrichment and burnup requirements of LCO 3.7.12, Spent Fuel Pool Storage, may be stored in Region 2 of Figure 4.3-1; and

f. keff < 1.0 if flooded with unborated water and keff 0.95 if flooded with borated water at a minimum soluble boron concentration described in the Bases for LCO 3.7.12 for normal and design basis criticality-related accident conditions, which includes an allowance for uncertainties (Region 2 racks).

4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. The maximum keff value, including all biases and uncertainties, shall be less than or equal to 0.95 with full density unborated water;

c. The maximum keff value, including all biases and uncertainties, shall be less than or equal to 0.98 with optimum moderation and full reflection conditions; and

d. A nominal 10.90 inch center-to-center distance between fuel assemblies placed in the new fuel storage racks.

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Technical Specifications Design Features 4.0 4.0 DESIGN FEATURES 4.3.2 Drainage The spent fuel pool is designed and shall be maintained to prevent inadvertent draining of the pool below a minimum water depth of 23 ft above the surface of the fuel storage racks.

4.3.3 Capacity The spent fuel pool is designed and shall be maintained with a storage capacity limited to no more than 889 fuel assemblies.

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Technical Specifications Design Features 4.0 FIGURE 4.1-1 Low Population Zone and Site Boundary Map Turkey Point Unit 7 4.0 - 4

Technical Specifications Design Features 4.0 FIGURE 4.1-2 Exclusion Area Boundary Turkey Point Unit 7 4.0 - 5

Technical Specifications Design Features 4.0 Region 1 (A1, A2, A3) - 243 locations Region 2 (B1, B2, B3, B4, C1) - 641 locations Defective Fuel Cells (DFCs) - 5 locations Total Storage Locations - 889 Figure 4.3-1 Discrete Two Region Spent Fuel Pool Rack Layout Turkey Point Unit 7 4.0 - 6

Technical Specifications Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operations and 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.

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Technical Specifications Organization 5.2 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 including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications shall be documented in the FSAR;

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. A specified corporate officer shall have corporate 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 radiation protection, 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 operation pressures.

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 operating in MODE 1, 2, 3, or 4.

b. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.e 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 absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

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Technical Specifications Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

c. A radiation protection 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. The operations manager or assistant operations manager shall hold an SRO license.

e. 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.

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Technical Specifications Unit Staff Qualifications 5.3 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 of Regulatory Guide 1.8, Revision 3, 2000, with the following exception:

a. During cold license operator training through the first refueling outage, the Regulatory Position C.1.b of Regulatory Guide 1.8, Revision 2, 1987, applies: cold license operator candidates meet the training elements defined in ANSI/ANS 3.1-1993 but are exempt from the experience requirements defined in ANSI/ANS 3.1-1993.

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).

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Technical Specifications Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 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, as stated in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

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Technical Specifications Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.5.1 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 Specification 5.6.2 and Specification 5.6.3.

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), and

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

c. Shall be submitted to the NRC in the form of a complete, legible copy of the changed portion of the 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.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.2 Radioactive Effluent Control 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 setpoints 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 ten times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20;

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 for radioactive materials in liquid effluents released form 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;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas 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 Turkey Point Unit 7 5.5 - 2

Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.2 Radioactive Effluent Control Program (continued)

2. For iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-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.

5.5.3 Inservice Testing Program This program provides control for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a. Testing frequencies specified in the ASME OM Code and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies Addenda Terminology for for performing inservice inservice testing activities 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 for performing inservice testing activities; Turkey Point Unit 7 5.5 - 3

Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.3 Inservice Testing Program (continued)

c. The provisions of SR 3.0.3 are applicable to inservice testing activities;

d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.4 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 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 cool down 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.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 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 a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 150 gpd per SG.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.7, "RCS Operational LEAKAGE."

c. Provisions for SG tube 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.

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 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 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 installation.

2. Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Steam Generator (SG) Program (continued)

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

5.5.5 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;

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.

5.5.6 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.6 Technical Specifications (TS) Bases Control Program (continued)

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. A change in the TS incorporated in the license; or

2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that meet the criteria of (b) above 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).

5.5.7 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate action 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 supported system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirement 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 systems Completion Time is not inappropriately extended as a result of multiple support systems inoperabilities; and

d. Other appropriate limitations and remedial or compensatory actions.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Safety Function Determination Program (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. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.8 Containment Leakage Rate Testing Program

a. 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 1.163, Performance-Based Containment Leak-Test Program, dated September 1995, as modified by approved exceptions.

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is 58.3 psig. The containment design pressure is 59 psig.

c. The maximum allowable primary containment leakage rate, La, at Pa, shall be 0.10% of primary containment air weight per day.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Containment Leakage Rate Testing Program (continued)

d. Leakage Rate acceptance criteria are:

1. Containment 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 Type B and Type C tests and 0.75 La for Type A tests;

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is 0.05 La when tested at Pa, b) For each door, leakage rate is 0.01 La when pressurized to 10 psig.

e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

5.5.9 System Level OPERABILITY Testing Program The System Level OPERABILITY Testing Program provides requirements for performance tests of passive systems. The System Level Inservice Tests specified in Section 3.9.6 and Table 3.9-17 apply when specified by individual Surveillance Requirements.

a. The provisions of SR 3.0.2 are applicable to the test frequencies specified in Table 3.9-17 for performing system level OPERABILITY testing activities; and

b. The provisions of SR 3.0.3 are applicable to system level OPERABILITY testing activities.

5.5.10 Component Cyclic or Transient Limit This program provides controls to track the Table 3.9-1A cyclic and transient occurrences to ensure that components are maintained within the design limits.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Battery Monitoring and Maintenance Program This Program provides for battery restoration and maintenance, based on the recommendations of IEEE Standard 450-1995, IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications, or of the battery manufacturer including the following:

a. Actions to restore battery cells with float voltage < 2.13 V, and

b. Actions to equalize and test battery cells that had been discovered with electrolyte level below the minimum established design limit.

5.5.12 Main Control Room Envelope Habitability Program A Main Control Room Envelope (MCRE) Habitability Program shall be established and implemented to ensure that MCRE habitability is maintained such that, with an OPERABLE Main Control Room Emergency Habitability System (VES),

MCRE 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 MCRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

a. The definition of the MCRE and the MCRE boundary.

b. Requirements for maintaining the MCRE boundary in its design condition, including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the MCRE boundary into the MCRE 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 MCRE 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 MCRE pressure relative to all external areas adjacent to the MCRE boundary during the pressurization mode of operation of one VES air delivery flow path, operating at the required flow rate of 65 +/- 5 scfm, at a Frequency of 24 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 24 month assessment of the MCRE boundary.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Main Control Room Envelope Habitability Program (continued)

e. The quantitative limits on unfiltered air inleakage into the MCRE. 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 MCRE 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 MCRE habitability, determining MCRE unfiltered inleakage, and measuring MCRE pressure and assessing the MCRE boundary as required by paragraphs c and d, respectively.

5.5.13 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of the VES.

Tests described in Specification 5.5.13.a and 5.5.13.b shall be performed:

i) initially, ii) once each 24 months, iii) after partial or complete replacement of a HEPA filter or charcoal adsorber, iv) after any detection of, or evidence of, penetration or intrusion of water or other material into any portion of the VES that may have an adverse effect on the functional capability of the filters, and v) following painting, fire, or chemical release in any ventilation zone communicating with the VES that may have an adverse effect on the functional capability of the system.

Tests described in Specification 5.5.13.c shall be performed: i) after each 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of system operation or at least once each 24 months, whichever comes first, ii) following painting, fire, or chemical release in any ventilation zone communicating with the VES that may have an adverse effect on the functional capability of the carbon media, and iii) following detection of, or evidence of, penetration or intrusion of water or other material into any portion of the VES that may have an adverse effect on the functional capability of the carbon media.

Tests described in 5.5.13.d shall be performed once per 24 months.

a. Demonstrate for the VES that an inplace test of the high efficiency particulate air (HEPA) filter shows a penetration and system bypass 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 3, and ASME N510-1989 at a flow rate at least 600 cfm greater than the flow measured by VES-FT-003A/B. The flow rate being measured is a combination of the VES breathable air supply flow and the recirculation flow drawn through the eductor.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation System Flow Rate VES 600 + VES supply flow (cfm)

b. Demonstrate for the VES that an inplace test of the charcoal adsorber shows a penetration and system bypass 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 3, and ASME N510-1989 at a flow rate at least 600 cfm greater than the flow measured by VES-FT-003A/B. The flow rate being measured is a combination of the VES breathable air supply flow and the recirculation flow drawn through the eductor.

ESF Ventilation System Flow Rate VES 600 + VES supply flow (cfm)

c. Demonstrate for the VES that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 3, 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 (86°F) and the relative humidity specified below.

ESF Ventilation System Penetration RH VES 5% 95%

d. Demonstrate for the VES that the pressure drop across the combined HEPA filter, the charcoal adsorber, and the post filter is less than the value specified below when tested at the system flow rate specified below +/- 10%.

ESF Ventilation System Delta P Flow Rate VES 5 in. water 660 cfm gauge The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.14 Setpoint Program (SP)

a. The Setpoint Program (SP) implements the regulatory requirement of 10 CFR 50.36(c)(1)(ii)(A) that technical specifications will include items in the category of limiting safety system settings (LSSS), which are settings for automatic protective devices related to those variables having significant safety functions.

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Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Setpoint Program (SP) (continued)

b. The Nominal Trip Setpoint (NTS), As-Found Tolerance (AFT), and As-Left Tolerance (ALT) for each Technical Specification required automatic protection instrumentation function shall be calculated in conformance with WCAP-16361-P, Westinghouse Setpoint Methodology for Protection Systems - AP1000, February 2011.

c. For each Technical Specification required automatic protection instrumentation function, performance of a CHANNEL CALIBRATION, CHANNEL OPERATIONAL TEST (COT), or REACTOR TRIP CHANNEL OPERATIONAL TEST (RTCOT) surveillance in accordance with the Setpoint Program shall include the following:

1. The as-found value of the instrument channel trip setting shall be compared with the previously recorded as-left value.

i. If the as-found value of the instrument channel trip setting differs from the previously recorded as-left value by more than the pre-defined test acceptance criteria band (i.e., the specified AFT),

then the instrument channel shall be evaluated to verify that it is functioning in accordance with its design basis before declaring the requirement met and returning the instrument channel to service.

An Instrument Channel is determined to be functioning in accordance with its design basis if it can be set to within the ALT.

This as-found condition shall be entered into the plants corrective action program.

ii. If the as-found value of the instrument channel trip setting is less conservative than the specified AFT, the surveillance requirement is not met and the instrument channel shall be immediately declared inoperable.

2. The instrument channel trip setting shall be set to a value within the specified ALT around the specified NTS at the completion of the surveillance; otherwise, the surveillance requirement is not met and the instrument channel shall be immediately declared inoperable.

Turkey Point Unit 7 5.5 - 13

Technical Specifications Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Setpoint Program (SP) (continued)

d. The difference between the instrument channel trip setting as-found value and the previously recorded as-left value for each Technical Specification required automatic protection instrumentation function shall be trended and evaluated to verify that the instrument channel is functioning in accordance with its design basis.

e. The SP shall establish a document containing the current value of the specified NTS, AFT, and ALT for each Technical Specification required automatic protection instrumentation function and references to the calculation documentation. Changes to this document shall be governed by the regulatory requirement of 10 CFR 50.59. In addition, changes to the specified NTS, AFT, and ALT values shall be governed by the approved setpoint methodology. This document, including any revisions or supplements, shall be provided upon issuance to the NRC.

Turkey Point Unit 7 5.5 - 14

Technical Specifications Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Occupational Radiation Exposure 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.

A tabulation on an annual basis of the number of station, utility, and other personnel (including contractors) receiving exposures > 100 mrem/yr and their associated collective deep dose equivalent (reported in person-rem) according to work and job functions (e.g., reactor operations and surveillance, inservice inspection, routine maintenance, special maintenance, waste processing, and refueling). This tabulation supplements the requirements of 10 CFR 20.2206. The dose assignments to various duty functions may be estimated based on pocket dosimeter, thermoluminescent dosimeter (TLD), electronic dosimeter or film badge measurements. Small exposures totaling < 20% of the individual total dose need not be accounted for. In the aggregate, at least 80% of the total deep dose equivalent received from external sources should be assigned to specific major work functions. The report shall be submitted by April 30 of each year. The initial report shall be submitted by April 30 of the year following the initial criticality.

5.6.2 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.

Turkey Point Unit 7 5.6 - 1

Technical Specifications Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radiological Environmental Operating Report (continued)

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.

5.6.3 Radioactive Effluent Release Report

- NOTE -

A single submittal may be made for a multiple unit station.

The Radioactive Effluent Release Report covering the operation of the unit in 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.

5.6.4 Monthly Operating Reports Routine reports of operating statistics and shutdown experience shall be submitted on a monthly basis no later than the 15th of each month following the calendar month covered by the report.

5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

2.1.1, Reactor Core SLs 3.1.1, SHUTDOWN MARGIN (SDM) 3.1.3, Moderator Temperature Coefficient 3.1.5, Shutdown Bank Insertion Limits 3.1.6, Control Bank Insertion Limits 3.2.1, Heat Flux Hot Channel Factor Turkey Point Unit 7 5.6 - 2

Technical Specifications Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (continued) 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor 3.2.3, AXIAL FLUX DIFFERENCE 3.2.5, OPDMS-monitored Power Distribution Parameters 3.3.1, Reactor Trip System (RTS) Instrumentation 3.4.1, RCS Pressure, Temperature, and DNB Limits 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:

1. WCAP-9272-P-A, Westinghouse Reload Safety Evaluation Methodology, July 1985 (Westinghouse Proprietary) and WCAP-9273-NP-A (Non-Proprietary).

(Methodology for Specifications 3.1.4 - Moderator Temperature Coefficient, 3.1.6 - Shutdown Bank Insertion Limits, 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-8385, Power Distribution Control and Load Following Procedures - Topical Report, September 1974 (Westinghouse Proprietary) and WCAP-8403 (Non-Proprietary).

(Methodology for Specification 3.2.3 - AXIAL FLUX DIFFERENCE (Constant Axial Offset Control).)

2b. T. M. Anderson to K. Kniel (Chief of Core Performance Branch, NRC)

January 31, 1980 -

Attachment:

Operation and Safety Analysis Aspects of an Improved Load Follow Package.

(Methodology for Specification 3.2.3 - AXIAL FLUX DIFFERENCE (Constant Axial Offset Control).)

2c. NUREG-0800, Standard Review Plan, U.S. Nuclear Regulatory Commission, Section 4.3, Nuclear Design, July 1981. Branch Technical Position CPB 4.3-1, Westinghouse Constant Axial Offset Control (CAOC), Rev. 2, July 1981.

(Methodology for Specification 3.2.3 - AXIAL FLUX DIFFERENCE (Constant Axial Offset Control).)

Turkey Point Unit 7 5.6 - 3

Technical Specifications Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (continued)

3. WCAP-10216-P-A, Revision 1A, Relaxation of Constant Axial Offset Control FQ Surveillance Technical Specification, February 1994 (Westinghouse Proprietary) and WCAP-10217-A (Non-Proprietary).

(Methodology for Specifications 3.2.3 - AXIAL FLUX DIFFERENCE (Relaxed Axial Offset Control) and 3.2.1 - Heat Flux Hot Channel Factor (W(Z) surveillance requirements for FQ Methodology).)

4. WCAP-12945-P-A, Volumes 1-5, Westinghouse Code Qualification Document for Best Estimate Loss of Coolant Accident Analysis, Revision 2, March 1998 (Westinghouse Proprietary) and WCAP-14747 (Non-Proprietary).

(Methodology for Specification 3.2.1 - Heat Flux Hot Channel Factor.)

5. WCAP-12472-P-A, BEACON Core Monitoring and Operations Support System, August 1994, Addendum 1, May 1996 (Westinghouse Proprietary), and Addendum 2, March 2001 (Westinghouse Proprietary) and WCAP-12473-A (Non-Proprietary).

(Methodology for Specification 3.2.5 - OPDMS - Monitored Power Distribution Parameters.)

6. APP-GW-GLR-137, Revision 1, Bases of Digital Overpower and Overtemperature Delta-T (OPT/OTT) Reactor Trips, Westinghouse Electric Company LLC.

(Methodology for Specification 2.1.1 - Reactor Core Safety Limits, and 3.3.1 - Reactor Trip System (RTD) Instrumentation.)

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Passive Core Cooling Systems 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.

Turkey Point Unit 7 5.6 - 4

Technical Specifications Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a. RCS pressure and temperature limits for heat up, 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:

3.4.3, RCS Pressure and Temperature (P/T) Limits 3.4.14, Low Temperature Overpressure Protection (LTOP) System

b. The analytical methods used to determine the RCS pressure and temperature limits shall be those previously reviewed and approved by the NRC, specifically those described in the following document:

WCAP-14040-A, Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves.

(Limits for LCO 3.4.3 and LCO 3.4.14).

c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluency period and for any revision or supplement thereto.

5.6.7 Post Accident Monitoring Report When a report is required by Condition B 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.

5.6.8 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 5.5.4, "Steam Generator (SG) Program." The report shall include:

a. The scope of inspections performed on each SG,

b. Active degradation 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, Turkey Point Unit 7 5.6 - 5

Technical Specifications Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Steam Generator Tube Inspection Report (continued)

e. Number of tubes plugged during the inspection outage for each active degradation mechanism,

f. Total number and percentage of tubes plugged to date,

g. The results of condition monitoring, including the results of tube pulls and in-situ testing, and

h. The effective plugging percentage for all plugging in each SG.

Turkey Point Unit 7 5.6 - 6

Technical Specifications High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 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:

5.7.1 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 or group 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 devices 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 Turkey Point Unit 7 5.7 - 1

Technical Specifications High Radiation Area 5.7 5.7 High Radiation Area 5.7.1 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.

5.7.2 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 supervisor, radiation protection manager, or his or her designees, and

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

Turkey Point Unit 7 5.7 - 2

Technical Specifications High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 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)

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 group entering such an area shall possess:

1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the devices 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

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under 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 surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, or 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.

Turkey Point Unit 7 5.7 - 3

Technical Specifications High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 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)

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 displaces 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.

Turkey Point Unit 7 5.7 - 4

ML17088A314

Text

Attachment:

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