NUREG-1434 Volume 1, Rev. 5, Standard Technical Specifications, General Electric BWR/6 Plants: Specifications

NUREG-1434, Vol. 1, Rev. 5, Standard Technical Specifications, General Electric BWR/6 Plants: Specifications

ML21271A582
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Issue date:	09/30/2021
From:	Michelle Honcharik Office of Nuclear Reactor Regulation
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NUREG-1434 V01 R05
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NUREG-1434 Volume 1 Revision 5.0 Standard Technical Specifications General Electric BWR/6 Plants Revision 5.0 Volume 1, Specifications Office of Nuclear Reactor Regulation

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NUREG-1434 Volume 1 Revision 5.0 Standard Technical Specifications General Electric BWR/6 Plants Revision 5.0 Volume 1, Specifications Manuscript Completed: March 2021 Date Published: September 2021 Office of Nuclear Reactor Regulation

ABSTRACT This NUREG contains the improved Standard Technical Specifications (STS) for Babcock and Wilcox (B&W) plants. The changes reflected in Revision 5 result from the experience gained from plant operation using the improved STS and extensive public technical meetings and discussions among the Nuclear Regulatory Commission (NRC) staff and various nuclear power plant licensees and the Nuclear Steam Supply System (NSSS) Owners Groups.

The improved STS were developed based on the criteria in the Final Commission Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors, dated July 22, 1993 (58 FR 39132), which was subsequently codified by changes to Section 36 of Part 50 of Title 10 of the Code of Federal Regulations (10 CFR 50.36) (60 FR 36953). Licensees are encouraged to upgrade their technical specifications consistent with those criteria and conforming, to the practical extent, to Revision 5 to the improved STS. The Commission continues to place the highest priority on requests for complete conversions to the improved STS. Licensees adopting portions of the improved STS to existing technical specifications should adopt all related requirements, as applicable, to achieve a high degree of standardization and consistency.

Users may access the STS NUREGs in the PDF format at https://www.nrc.gov/reading-rm/doc-collections/nuregs/staff/. Users may print or download copies from the NRC Web site.

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PUBLIC PROTECTION NOTIFICATION The NRC may not conduct or sponsor, and a person is not required to respond to, a collection of information unless the document requesting or requiring the collection displays a currently valid OMB control number.

General Electric BWR/6 STS iii Rev. 5.0

TABLE OF CONTENTS Page ABSTRACT ............................................................................................................... iii 1.0 USE AND APPLICATION ........................................................................................ 1.1-1 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) ............................................................................................. 2.0-1 2.1 Safety Limits ....................................................................................................... 2.0-1 2.2 SL Violations ...................................................................................................... 2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ........................ 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ....................................... 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS .................................................................... 3.1.1-1 3.1.1 SHUTDOWN MARGIN (SDM) ........................................................................ 3.1.1-1 3.1.2 Reactivity Anomalies ....................................................................................... 3.1.2-1 3.1.3 Control Rod OPERABILITY............................................................................. 3.1.3-1 3.1.4 Control Rod Scram Times ............................................................................... 3.1.4-1 3.1.5 Control Rod Scram Accumulators ................................................................... 3.1.5-1 3.1.6 Rod Pattern Control......................................................................................... 3.1.6-1 3.1.7 Standby Liquid Control (SLC) System ............................................................. 3.1.7-1 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ................................ 3.1.8-1 3.2 POWER DISTRIBUTION LIMITS .......................................................................... 3.2.1-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) ................................................................................................. 3.2.1-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) .............................................. 3.2.2-1 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) (Optional) ............................... 3.2.3-1 3.2.4 Average Power Range Monitor (APRM) Gain and Setpoints (Optional) ................................................................................................... 3.2.4-1 3.3 INSTRUMENTATION ......................................................................................... 3.3.1.1-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation ...................................... 3.3.1.1-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation ............................................ 3.3.1.2-1 3.3.2.1 Control Rod Block Instrumentation ............................................................... 3.3.2.1-1 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ......................................... 3.3.3.1-1 3.3.3.2 Remote Shutdown System ........................................................................... 3.3.3.2-1 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ............ 3.3.4.1-1 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation................................................................. 3.3.4.2-1 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ......................... 3.3.5.1-1 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation ....................................................................................... 3.3.5.2-1 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation ................. 3.3.5.3-1 3.3.6.1 Primary Containment Isolation Instrumentation ........................................... 3.3.6.1-1 3.3.6.2 Secondary Containment Isolation Instrumentation ....................................... 3.3.6.2-1 3.3.6.3 Residual Heat Removal (RHR) Containment Spray System Instrumentation ....................................................................................... 3.3.6.3-1 General Electric BWR/6 STS v Rev. 5.0

TABLE OF CONTENTS Page 3.3 INSTRUMENTATION (continued) 3.3.6.4 Suppression Pool Makeup (SPMU) System Instrumentation ....................... 3.3.6.4-1 3.3.6.5 Relief and Low-Low Set (LLS) Instrumentation ............................................ 3.3.6.5-1 3.3.7.1 [Control Room Fresh Air (CRFA)] System Instrumentation .......................... 3.3.7.1-1 3.3.8.1 Loss of Power (LOP) Instrumentation .......................................................... 3.3.8.1-1 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ...................... 3.3.8.2-1 3.4 REACTOR COOLANT SYSTEM (RCS) ............................................................... 3.4.1-1 3.4.1 Recirculation Loops Operating ........................................................................ 3.4.1-1 3.4.2 Flow Control Valves (FCVs) ............................................................................ 3.4.2-1 3.4.3 Jet Pumps ....................................................................................................... 3.4.3-1 3.4.4 Safety/Relief Valves (S/RVs) ........................................................................... 3.4.4-1 3.4.5 RCS Operational LEAKAGE ........................................................................... 3.4.5-1 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage ................................................. 3.4.6-1 3.4.7 RCS Leakage Detection Instrumentation ........................................................ 3.4.7-1 3.4.8 RCS Specific Activity ....................................................................................... 3.4.8-1 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown .................................................................................................. 3.4.9-1 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown ................................................................................................ 3.4.10-1 3.4.11 RCS Pressure and Temperature (P/T) Limits ............................................... 3.4.11-1 3.4.12 Reactor Steam Dome Pressure .................................................................... 3.4.12-1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM .................................................................................. 3.5.1-1 3.5.1 ECCS - Operating ........................................................................................... 3.5.1-1 3.5.2 RPV Water Inventory Control .......................................................................... 3.5.2-1 3.5.3 RCIC System................................................................................................... 3.5.3-1 3.6 CONTAINMENT SYSTEMS ............................................................................... 3.6.1.1-1 3.6.1.1 Primary Containment.................................................................................... 3.6.1.1-1 3.6.1.2 Primary Containment Air Locks .................................................................... 3.6.1.2-1 3.6.1.3 Primary Containment Isolation Valves (PCIVs) ............................................ 3.6.1.3-1 3.6.1.4 Primary Containment Pressure .................................................................... 3.6.1.4-1 3.6.1.5 Primary Containment Air Temperature ......................................................... 3.6.1.5-1 3.6.1.6 Low-Low Set (LLS) Valves ........................................................................... 3.6.1.6-1 3.6.1.7 Residual Heat Removal (RHR) Containment Spray System ........................ 3.6.1.7-1 3.6.1.8 Penetration Valve Leakage Control System (PVLCS) ................................. 3.6.1.8-1 3.6.1.9 Main Steam Isolation Valve (MSIV) Leakage Control System (LCS) ........... 3.6.1.9-1 3.6.2.1 Suppression Pool Average Temperature ..................................................... 3.6.2.1-1 3.6.2.2 Suppression Pool Water Level ..................................................................... 3.6.2.2-1 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling .......................... 3.6.2.3-1 3.6.2.4 Suppression Pool Makeup (SPMU) System ................................................. 3.6.2.4-1 3.6.3.1 Primary Containment and Drywell Hydrogen Ignitors ................................. 3.6.3.1-1 3.6.3.2 [Drywell Purge System ............................................................................... 3.6.3.2-1 ]

3.6.4.1 [Secondary Containment ............................................................................ 3.6.4.1-1 ]

3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ....................................... 3.6.4.2-1 3.6.4.3 Standby Gas Treatment (SGT) System ....................................................... 3.6.4.3-1 General Electric BWR/6 STS vi Rev. 5.0

TABLE OF CONTENTS Page 3.6 CONTAINMENT SYSTEMS (continued) 3.6.5.1 Drywell.......................................................................................................... 3.6.5.1-1 3.6.5.2 Drywell Air Lock............................................................................................ 3.6.5.2-1 3.6.5.3 Drywell Isolation Valves .............................................................................. 3.6.5.3-1 3.6.5.4 Drywell Pressure .......................................................................................... 3.6.5.4-1 3.6.5.5 Drywell Air Temperature............................................................................... 3.6.5.5-1 3.6.5.6 Drywell Vacuum Relief System .................................................................... 3.6.5.6-1 3.7 PLANT SYSTEMS ................................................................................................ 3.7.1-1 3.7.1 [Standby Service Water (SSW)] System and [Ultimate Heat Sink (UHS)] ....................................................................................................... 3.7.1-1 3.7.2 High Pressure Core Spray (HPCS) Service Water System (SWS) ................. 3.7.2-1 3.7.3 [Control Room Fresh Air (CRFA)] System ...................................................... 3.7.3-1 3.7.4 [Control Room Air Conditioning (AC)] System ................................................ 3.7.4-1 3.7.5 Main Condenser Offgas .................................................................................. 3.7.5-1 3.7.6 Main Turbine Bypass System .......................................................................... 3.7.6-1 3.7.7 Fuel Pool Water Level ..................................................................................... 3.7.7-1 3.8 ELECTRICAL POWER SYSTEMS ....................................................................... 3.8.1-1 3.8.1 AC Sources - Operating .................................................................................. 3.8.1-1 3.8.2 AC Sources - Shutdown .................................................................................. 3.8.2-1 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ....................................................... 3.8.3-1 3.8.4 DC Sources - Operating .................................................................................. 3.8.4-1 3.8.5 DC Sources - Shutdown .................................................................................. 3.8.5-1 3.8.6 Battery Parameters ......................................................................................... 3.8.6-1 3.8.7 Inverters - Operating ....................................................................................... 3.8.7-1 3.8.8 Inverters - Shutdown ....................................................................................... 3.8.8-1 3.8.9 Distribution Systems - Operating..................................................................... 3.8.9-1 3.8.10 Distribution Systems - Shutdown .................................................................. 3.8.10-1 3.9 REFUELING OPERATIONS ................................................................................. 3.9.1-1 3.9.1 Refueling Equipment Interlocks....................................................................... 3.9.1-1 3.9.2 Refuel Position One-Rod-Out Interlock ........................................................... 3.9.2-1 3.9.3 Control Rod Position ....................................................................................... 3.9.3-1 3.9.4 Control Rod Position Indication ....................................................................... 3.9.4-1 3.9.5 Control Rod OPERABILITY - Refueling .......................................................... 3.9.5-1 3.9.6 [RPV] Water Level [- Irradiated Fuel] .............................................................. 3.9.6-1 3.9.7 [RPV] Water Level - New Fuel or Control Rods ............................................ 3.9.7-1 ]

3.9.8 Residual Heat Removal (RHR) - High Water Level ......................................... 3.9.8-1 3.9.9 Residual Heat Removal (RHR) - Low Water Level ......................................... 3.9.9-1 3.10 SPECIAL OPERATIONS .................................................................................... 3.10.1-1 3.10.1 Inservice Leak and Hydrostatic Testing Operation ........................................ 3.10.1-1 3.10.2 Reactor Mode Switch Interlock Testing ......................................................... 3.10.2-1 3.10.3 Single Control Rod Withdrawal - Hot Shutdown ............................................ 3.10.3-1 3.10.4 Single Control Rod Withdrawal - Cold Shutdown .......................................... 3.10.4-1 3.10.5 Single Control Rod Drive (CRD) Removal - Refueling .................................. 3.10.5-1 3.10.6 Multiple Control Rod Withdrawal - Refueling................................................. 3.10.6-1 General Electric BWR/6 STS vii Rev. 5.0

TABLE OF CONTENTS Page 3.10 SPECIAL OPERATIONS (continued) 3.10.7 Control Rod Testing - Operating ................................................................... 3.10.7-1 3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling ............................................ 3.10.8-1 3.10.9 Recirculation Loops - Testing ........................................................................ 3.10.9-1 3.10.10 Training Startups ......................................................................................... 3.10.10-1 4.0 DESIGN FEATURES ............................................................................................... 4.0-1 4.1 Site Location ...................................................................................................... 4.0-1 4.2 Reactor Core ...................................................................................................... 4.0-1 4.3 Fuel Storage ....................................................................................................... 4.0-1 5.0 ADMINISTRATIVE CONTROLS .............................................................................. 5.1-1 5.1 Responsibility ..................................................................................................... 5.1-1 5.2 Organization ....................................................................................................... 5.2-1 5.3 Unit Staff Qualifications ...................................................................................... 5.3-1 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 General Electric BWR/6 STS viii Rev. 5.0

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

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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.

AVERAGE PLANAR LINEAR The APLHGR shall be applicable to a specific planar height HEAT GENERATION RATE and is equal to the sum of the [LHGRs] [heat generation rate (APLHGR) per unit length of fuel rod] for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle [at the height].

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary 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 channel OPERABILITY and the CHANNEL FUNCTIONAL TEST. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps[, and each step must be performed within the Frequency in the Surveillance Frequency Control Program for the devices included in the step].

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.

General Electric BWR/6 STS 1.1-1 Rev. 5.0

Definitions 1.1 1.1 Definitions CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps[, and each step must be performed within the Frequency in the Surveillance Frequency Control Program for the devices included in the step].

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.

The following exceptions are not considered to be CORE ALTERATIONS:

a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement), and

b. Control rod movement, provided there are no fuel assemblies in the associated core cell.

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 limits shall be determined for each reload cycle in accordance with Specification 5.6.3. Plant operation within these limits is addressed in individual Specifications.

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

[Table III of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites" or those listed in Table E-7 of Regulatory Guide 1.109, Rev. 1, NRC, 1977, or ICRP 30, Supplement to Part 1, page 192-212, Table titled, "Committed Dose Equivalent in Target Organs or Tissues per Intake of Unit Activity"].

General Electric BWR/6 STS 1.1-2 Rev. 5.0

Definitions 1.1 1.1 Definitions DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a) The water inventory above the TAF is divided by the limiting drain rate; b) The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure, for all penetration flow paths below the TAF except:

1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are closed and administratively controlled in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.

c) The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory; d) No additional draining events occur; and e) Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

General Electric BWR/6 STS 1.1-3 Rev. 5.0

Definitions 1.1 1.1 Definitions EMERGENCY CORE COOLING The ECCS RESPONSE TIME shall be that time interval from SYSTEM (ECCS) RESPONSE when the monitored parameter exceeds its ECCS initiation TIME setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

END OF CYCLE RECIRCULA- The EOC-RPT SYSTEM RESPONSE TIME shall be that time TION PUMP TRIP (EOC-RPT) interval from initial signal generation by [the associated turbine SYSTEM RESPONSE TIME stop valve limit switch or from when the turbine control valve hydraulic oil control oil pressure drops below the pressure switch setpoint] to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker. 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, [except for the breaker arc suppression time, which is not measured but is validated to conform to the manufacturer's design value].

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

ISOLATION SYSTEM The ISOLATION SYSTEM RESPONSE TIME shall be that RESPONSE TIME time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves travel to their required positions. Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

General Electric BWR/6 STS 1.1-4 Rev. 5.0

Definitions 1.1 1.1 Definitions LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell such as that from pump seals or valve packing that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known to not interfere with the operation of leakage detection systems;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE;

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE; and

d. Pressure Boundary LEAKAGE LEAKAGE through a fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

LEAKAGE past seals, packing, and gaskets is not pressure boundary LEAKAGE.

[ LINEAR HEAT GENERATION The LHGR shall be the heat generation rate per unit length of RATE (LHGR) fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length. ]

LOGIC SYSTEM FUNCTIONAL A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all TEST logic components required for OPERABILITY of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

[ MAXIMUM FRACTION OF The MFLPD shall be the largest value of the fraction of limiting LIMITING POWER DENSITY power density in the core. The fraction of limiting power (MFLPD) density shall be the LHGR existing at a given location divided by the specified LHGR limit for that bundle type. ]

General Electric BWR/6 STS 1.1-5 Rev. 5.0

Definitions 1.1 1.1 Definitions MINIMUM CRITICAL POWER The MCPR shall be the smallest critical power ratio (CPR) that RATIO (MCPR) exists in the core [for each class of fuel]. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

MODE A MODE shall correspond to any one inclusive combination of mode switch position, 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, division, 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, division, 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] of the FSAR,

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

c. Otherwise approved by the Nuclear Regulatory Commission.

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 5.6.4.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of [3833] MWt.

General Electric BWR/6 STS 1.1-6 Rev. 5.0

Definitions 1.1 1.1 Definitions REACTOR PROTECTION The RPS RESPONSE TIME shall be that time interval from SYSTEM (RPS) RESPONSE when the monitored parameter exceeds its RPS trip setpoint at TIME the channel sensor until de-energization of the scram pilot valve solenoids. 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 amount of reactivity by which the reactor is subcritical or would be subcritical throughout the operating cycle assuming that:

a. The reactor is xenon free,

b. The moderator temperature is 68F, corresponding to the most reactive state; and

c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn. With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.

[ 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.

General Electric BWR/6 STS 1.1-7 Rev. 5.0

Definitions 1.1 1.1 Definitions

[ TURBINE BYPASS SYSTEM The TURBINE BYPASS SYSTEM RESPONSE TIME consists RESPONSE TIME of two components:

a. The time from initial movement of the main turbine stop valve or control valve until 80% of the turbine bypass capacity is established and

b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve.

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. ]

General Electric BWR/6 STS 1.1-8 Rev. 5.0

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

MODES AVERAGE REACTOR COOLANT REACTOR MODE TEMPERATURE MODE TITLE SWITCH POSITION (F) 1 Power Operation Run NA 2 Startup Refuel(a) or Startup/Hot Standby NA 3 Hot Shutdown(a) Shutdown > [200]

4 Cold Shutdown(a) Shutdown [200]

5 Refueling(b) Shutdown or Refuel NA (a) All reactor vessel head closure bolts fully tensioned.

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

General Electric BWR/6 STS 1.1-9 Rev. 5.0

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 (TS) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

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 by 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.

General Electric BWR/6 STS 1.2-1 Rev. 5.0

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.

General Electric BWR/6 STS 1.2-2 Rev. 5.0

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.

General Electric BWR/6 STS 1.2-3 Rev. 5.0

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 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.

Unless otherwise specified, the Completion Time begins when a senior licensed operator on the operating shift crew with responsibility for plant operations makes the determination that an LCO is not met and an ACTIONS Condition is entered. The "otherwise specified" exceptions are varied, such as a Required Action Note or Surveillance Requirement Note that provides an alternative time to perform specific tasks, such as testing, without starting the Completion Time. While utilizing the Note, should a Condition be applicable for any reason not addressed by the Note, the Completion Time begins. Should the time allowance in the Note be exceeded, the Completion Time begins at that point. The exceptions may also be incorporated into the Completion Time. For example, LCO 3.8.1, "AC Sources - Operating," Required Action B.2, requires declaring required feature(s) supported by an inoperable diesel generator, inoperable when the redundant required feature(s) are inoperable. The Completion Time states, "4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoperability of redundant required feature(s)." In this case the Completion Time does not begin until the conditions in the Completion Time are satisfied.

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 General Electric BWR/6 STS 1.3-1 Rev. 5.0

Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued) associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the discovery of the situation that required entry into the Condition, unless otherwise specified.

Once a Condition has been entered, subsequent divisions, 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, unless otherwise specified.

However, when a subsequent division, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 division, 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.

General Electric BWR/6 STS 1.3-2 Rev. 5.0

Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued)

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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />," 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 . . ."

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. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> 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 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND in MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. A total of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (not 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, the time allowed for reaching MODE 4 is the next 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> because the total time allowed for reaching MODE 4 is 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

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

General Electric BWR/6 STS 1.3-3 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

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

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> When a pump is declared inoperable, Condition A is entered. If the pump 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 pump is restored to OPERABLE status after Condition B is entered, Conditions A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump.

LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. 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 pumps 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 pumps 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.

General Electric BWR/6 STS 1.3-4 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

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

inoperable.

B. One B.1 Restore Function Y 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Function Y subsystem to subsystem OPERABLE status.

inoperable.

C. One C.1 Restore Function X 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Function X subsystem to subsystem OPERABLE status.

inoperable.

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

subsystem inoperable.

When one Function X subsystem and one Function Y subsystem are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem starting from the time each subsystem was declared General Electric BWR/6 STS 1.3-5 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem 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 subsystem was declared inoperable (i.e., initial entry into Condition A).

It is 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. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended.

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 <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 1.3-6 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

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 <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

If the Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> (plus the extension) expires while one or more valves are still inoperable, Condition B is entered.

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 <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> 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 applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

General Electric BWR/6 STS 1.3-7 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

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 that 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.

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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> inoperable.

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

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval of Required Action A.1 General Electric BWR/6 STS 1.3-8 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) 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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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.

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

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

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter" interval begins upon performance of Required Action A.1.

General Electric BWR/6 STS 1.3-9 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or any subsequent 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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.

---

Reviewer's Note -------------------------------------

Example 1.3-8 is only applicable to plants that have adopted the Risk Informed Completion Time Program.

[ EXAMPLE 1.3-8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore subsystem 7 days subsystem to OPERABLE inoperable. status. OR In accordance with the Risk Informed Completion Time Program B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action and associated AND Completion Time not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> When a subsystem is declared inoperable, Condition A is entered. The 7 day Completion Time may be applied as discussed in Example 1.3-2.

However, the licensee may elect to apply the Risk Informed Completion Time Program which permits calculation of a Risk Informed Completion General Electric BWR/6 STS 1.3-10 Rev. 5.0

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

Time (RICT) that may be used to complete the Required Action beyond the 7 day Completion Time. The RICT cannot exceed 30 days. After the 7 day Completion Time has expired, the subsystem must be restored to OPERABLE status within the RICT or Condition B must also be entered.

The Risk Informed Completion Time Program requires recalculation of the RICT to reflect changing plant conditions. For planned changes, the revised RICT must be determined prior to implementation of the change in configuration. For emergent conditions, the revised RICT must be determined within the time limits of the Required Action Completion Time (i.e., not the RICT) or 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after the plant configuration change, whichever is less.

If the 7 day Completion Time clock of Condition A has expired and subsequent changes in plant condition result in exiting the applicability of the Risk Informed Completion Time Program without restoring the inoperable subsystem to OPERABLE status, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start.

If the RICT expires or is recalculated to be less than the elapsed time since the Condition was entered and the inoperable subsystem has not been restored to OPERABLE status, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable subsystems are restored to OPERABLE status after Condition B is entered, Condition A is exited, and therefore, the Required Actions of Condition B may be terminated. ]

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

General Electric BWR/6 STS 1.3-11 Rev. 5.0

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 3.0.2, 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 Surveillance, 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 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 General Electric BWR/6 STS 1.4-1 Rev. 5.0

Frequency 1.4 1.4 Frequency DESCRIPTION (continued)

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 discuss 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.

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, an extension of the time interval to 1.25 times the interval specified in the 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 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 Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable.

General Electric BWR/6 STS 1.4-2 Rev. 5.0

Frequency 1.4 1.4 Frequency EXAMPLES (continued)

If the interval as 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.

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 25% RTP AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 reactor power is increased from a power level

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

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.

General Electric BWR/6 STS 1.4-3 Rev. 5.0

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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after power reaches 25% RTP to perform the Surveillance.

The Surveillance is still considered to be within the "specified Frequency."

Therefore, if the Surveillance were not performed within the 7 day interval (plus the extension allowed by SR 3.0.2), 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (plus the extension allowed by SR 3.0.2) with power 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> interval (plus the extension allowed by SR 3.0.2), there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

General Electric BWR/6 STS 1.4-4 Rev. 5.0

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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> interval (plus the extension allowed by SR 3.0.2) interval, 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency were not met), SR 3.0.4 would require satisfying the SR.

General Electric BWR/6 STS 1.4-5 Rev. 5.0

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.

General Electric BWR/6 STS 1.4-6 Rev. 5.0

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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency were not met), SR 3.0.4 would require satisfying the SR.

General Electric BWR/6 STS 1.4-7 Rev. 5.0

SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs 2.1.1.1 With the reactor steam dome pressure < 785 psig or core flow < 10%

rated core flow:

THERMAL POWER shall be 25% RTP.

2.1.1.2 With the reactor steam dome pressure 785 psig and core flow 10%

rated core flow:

MCPR shall be [1.07] [for two recirculation loop operation or [1.08]

for single recirculation loop operation.]

2.1.1.3 Reactor vessel water level shall be greater than the top of active irradiated fuel.

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be 1325 psig.

2.2 SL VIOLATIONS With any SL violation, the following actions shall be completed within 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />s:

2.2.1 Restore compliance with all SLs; and 2.2.2 Insert all insertable control rods.

General Electric BWR/6 STS 2.0-1 Rev. 5.0

LCO Applicability 3.0 3.0 LIMITING CONDITION 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 3.0.7, LCO 3.0.8, and LCO 3.0.9.

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 LCO 3.0.6.

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

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 <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, in:

a. MODE 2 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />,

b. MODE 3 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />, and

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

Exceptions to this Specification are stated in the individual Specifications.

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

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

LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time;

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate (exceptions to this Specification are stated in the individual Specifications); or

c. When an allowance is stated in the individual value, parameter, or other Specification.

General Electric BWR/6 STS 3.0-1 Rev. 5.0

LCO Applicability 3.0 LCO Applicability LCO 3.0.4 (continued)

This Specification shall not prevent changes in 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.

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 testing 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, an evaluation shall be performed in accordance with Specification 5.5.11, "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 system's 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 Special Operations LCOs in Section 3.10 allow specified Technical Specifications (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain LCO 3.0.7 unchanged. Compliance with Special Operations LCOs is optional. When a Special Operations LCO is desired to be met but is not met, the ACTIONS of the Special Operations LCO shall be met. When a Special Operations LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with the other applicable Specifications.

LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and:

General Electric BWR/6 STS 3.0-2 Rev. 5.0

LCO Applicability 3.0 LCO Applicability LCO 3.0.8 (continued)

a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; or

b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared not met.

LCO 3.0.9 When one or more required barriers are unable to perform their related support function(s), any supported system LCO(s) are not required to be declared not met solely for this reason for up to 30 days provided that at least one train or subsystem of the supported system is OPERABLE and supported by barriers capable of providing their related support function(s), and risk is assessed and managed. This specification may be concurrently applied to more than one train or subsystem of a multiple train or subsystem supported system provided at least one train or subsystem of the supported system is OPERABLE and the barriers supporting each of these trains or subsystems provide their related support function(s) for different categories of initiating events.

[ For the purposes of this specification, the [High Pressure Coolant Injection/High Pressure Core Spray] System, the [Reactor Core Isolation Cooling] System, and the [Automatic Depressurization System] are considered independent subsystems of a single system. ]

If the required OPERABLE train or subsystem becomes inoperable while this specification is in use, it must be restored to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or the provisions of this specification cannot be applied to the trains or subsystems supported by the barriers that cannot perform their related support function(s).

At the end of the specified period, the required barriers must be able to perform their related support function(s) or the supported system LCO(s) shall be declared not met.

General Electric BWR/6 STS 3.0-3 Rev. 5.0

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 for individual LCOs, unless otherwise stated in the SR.

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

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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. The delay period is only applicable when there is a reasonable expectation the Surveillance will be met when performed. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and the risk impact shall be managed.

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

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.

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

General Electric BWR/6 STS 3.0-4 Rev. 5.0

SR Applicability 3.0 SR Applicability SR 3.0.4 (continued)

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.

General Electric BWR/6 STS 3.0-5 Rev. 5.0

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

LCO 3.1.1 SDM shall be:

a. [0.38] % k/k, with the highest worth control rod analytically determined or

b. [0.28] % k/k, with the highest worth control rod determined by test.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limits in A.1 Restore SDM to within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> MODE 1 or 2. limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met.

C. SDM not within limits in C.1 Initiate action to fully insert Immediately MODE 3. all insertable control rods.

D. SDM not within limits in D.1 Initiate action to fully insert Immediately MODE 4. all insertable control rods.

AND D.2 Initiate action to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />

[secondary containment] to OPERABLE status.

AND General Electric BWR/6 STS 3.1.1-1 Rev. 5.0

SDM 3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.3 [ Initiate action to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ]

one standby gas treatment (SGT) subsystem to OPERABLE status.

AND D.4 Initiate action to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> isolation capability in each required [secondary containment] penetration flow path not isolated.

E. SDM not within limits in E.1 Suspend CORE Immediately MODE 5. ALTERATIONS except for control rod insertion and fuel assembly removal.

AND E.2 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies.

AND E.3 Initiate action to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />

[secondary containment] to OPERABLE status.

AND General Electric BWR/6 STS 3.1.1-2 Rev. 5.0

SDM 3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.4 [ Initiate action to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ]

one SGT subsystem to OPERABLE status.

AND E.5 Initiate action to restore 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> isolation capability in each required [secondary containment] penetration flow path not isolated.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. Prior to each in vessel fuel movement during fuel loading sequence AND Once within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after criticality following fuel movement within the reactor pressure vessel or control rod replacement General Electric BWR/6 STS 3.1.1-3 Rev. 5.0

Reactivity Anomalies 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Reactivity Anomalies LCO 3.1.2 The reactivity [difference] between the [monitored core keff and the predicted core keff] shall be within +/- 1% k/k.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity A.1 Restore core reactivity 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />

[difference] not within [difference] to within limit.

limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

General Electric BWR/6 STS 3.1.2-1 Rev. 5.0

Reactivity Anomalies 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify core reactivity [difference] between the Once within

[monitored core keff and the predicted core keff] is 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after within +/- 1% k/k. reaching equilibrium conditions following startup after fuel movement within the reactor pressure vessel or control rod replacement AND 1000 MWD/T thereafter during operations in MODE 1 General Electric BWR/6 STS 3.1.2-2 Rev. 5.0

Control Rod OPERABILITY 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Control Rod OPERABILITY LCO 3.1.3 Each control rod shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

Separate Condition entry is allowed for each control rod.

CONDITION REQUIRED ACTION COMPLETION TIME A. One withdrawn control --------------------NOTE-------------------

rod stuck. A stuck rod may be bypassed in the Rod Action Control System (RACS) in accordance with SR 3.3.2.1.9 if required to allow continued operation.

A.1 Verify stuck control rod Immediately separation criteria are met.

AND A.2 Disarm the associated 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> control rod drive (CRD).

AND General Electric BWR/6 STS 3.1.3-1 Rev. 5.0

Control Rod OPERABILITY 3.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.3 Perform SR 3.1.3.2 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from each withdrawn discovery of OPERABLE control rod. Condition A concurrent with THERMAL POWER greater than the low power setpoint (LPSP) of the Rod Pattern Controller AND A.4 Perform SR 3.1.1.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> B. Two or more withdrawn B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> control rods stuck.

C. One or more control C.1 ---------------NOTE--------------

rods inoperable for Inoperable control rods may reasons other than be bypassed in RACS in Condition A or B. accordance with SR 3.3.2.1.9, if required, to allow insertion of inoperable control rod and continued operation.

Fully insert inoperable 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> control rod.

AND C.2 Disarm the associated 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> CRD.

General Electric BWR/6 STS 3.1.3-2 Rev. 5.0

Control Rod OPERABILITY 3.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. ------------NOTE------------ D.1 Restore compliance with 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Not applicable when BPWS.

THERMAL POWER

> [10]% RTP. OR D.2 Restore control rod to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Two or more inoperable OPERABLE status.

control rods not in compliance with banked position withdrawal sequence (BPWS) and not separated by two or more OPERABLE control rods.

E. ------------NOTE------------ E.1 Restore the control rod to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> ]

[ Not applicable when OPERABLE status.

THERMAL POWER

> [10]% RTP.

One or more groups with four or more inoperable control rods.

F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, C, D, or E not met.

OR Nine or more control rods inoperable.

General Electric BWR/6 STS 3.1.3-3 Rev. 5.0

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.3.2 -------------------------------NOTE------------------------------

Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RPCS.

Insert each withdrawn control rod at least one notch. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.3.3 Verify each control rod scram time from fully In accordance withdrawn to notch position [13] is [ ] seconds. with SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 General Electric BWR/6 STS 3.1.3-4 Rev. 5.0

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.3.4 Verify each control rod does not go to the withdrawn Each time the overtravel position. control rod is withdrawn to "full out" position AND Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling General Electric BWR/6 STS 3.1.3-5 Rev. 5.0

Control Rod Scram Times 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than [14] OPERABLE control rods shall be "slow," in accordance with Table 3.1.4-1 and

b. No more than 2 OPERABLE control rods that are "slow" shall occupy adjacent locations.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> LCO not met.

SURVEILLANCE REQUIREMENTS

---

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

During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.

SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after

[950] psig. each reactor shutdown 120 days General Electric BWR/6 STS 3.1.4-1 Rev. 5.0

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.4.2 Verify, for a representative sample, each tested [ [200] days control rod scram time is within the limits of cumulative Table 3.1.4-1 with reactor steam dome pressure operation in

[950] psig. MODE 1 OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam control rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time SR 3.1.4.4 Verify each affected control rod scram time is within Prior to exceeding the limits of Table 3.1.4-1 with reactor steam dome 40% RTP after pressure [950] psig. fuel movement within the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time General Electric BWR/6 STS 3.1.4-2 Rev. 5.0

Control Rod Scram Times 3.1.4 Table 3.1.4-1 Control Rod Scram Times

---

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

1. OPERABLE control rods with scram times not within the limits of this Table are considered "slow."

2. Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod OPERABILITY," for control rods with scram times > [ ] seconds to notch position [13].

These control rods are inoperable, in accordance with SR 3.1.3.3, and are not considered "slow."

SCRAM TIMES(a)(b)

(seconds)

REACTOR STEAM REACTOR STEAM DOME DOME PRESSURE(c) PRESSURE(c)

NOTCH POSITION [950] psig [1050] psig

[43] [0.30] [0.31]

[29] [0.78] [0.84]

[13] [1.40] [1.53]

(a) Maximum scram time from fully withdrawn position, based on de-energization of scram pilot valve solenoids as time zero.

(b) Scram times as a function of reactor steam dome pressure, when < 950 psig, are within established limits.

(c) For intermediate reactor steam dome pressures, the scram time criteria are determined by linear interpolation.

General Electric BWR/6 STS 3.1.4-3 Rev. 5.0

Control Rod Scram Accumulators 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCO 3.1.5 Each control rod scram accumulator shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETION TIME A. One control rod scram A.1 ---------------NOTE--------------

accumulator inoperable Only applicable if the with reactor steam dome associated control rod pressure [900] psig. scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the associated 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> control rod scram time "slow."

OR A.2 Declare the associated 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> control rod inoperable.

B. Two or more control rod B.1 Restore charging water 20 minutes from scram accumulators header pressure to discovery of inoperable with reactor [1520] psig. Condition B steam dome pressure concurrent with

[900] psig. charging water header pressure

< [1520] psig AND General Electric BWR/6 STS 3.1.5-1 Rev. 5.0

Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2.1 ---------------NOTE--------------

Only applicable if the associated control rod scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> control rod scram time "slow."

OR B.2.2 Declare the associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> control rod inoperable.

C. One or more control rod C.1 Verify all control rods Immediately upon scram accumulators associated with inoperable discovery of charging inoperable with reactor accumulators are fully water header steam dome pressure inserted. pressure

< [900] psig. < [1520] psig AND C.2 Declare the associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> control rod inoperable.

D. Required Action and D.1 ---------------NOTE--------------

associated Completion Not applicable if all Time of Required inoperable control rod Action B.1 or C.1 not scram accumulators are met. associated with fully inserted control rods.

Place the reactor mode Immediately switch in the shutdown position.

General Electric BWR/6 STS 3.1.5-2 Rev. 5.0

Control Rod Scram Accumulators 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator pressure [ 7 days is [1520] psig.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.1.5-3 Rev. 5.0

Rod Pattern Control 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Rod Pattern Control LCO 3.1.6 OPERABLE control rods shall comply with the requirements of the

[banked position withdrawal sequence (BPWS)].

APPLICABILITY: MODES 1 and 2 with THERMAL POWER [10]% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 ---------------NOTE--------------

OPERABLE control rods Affected control rods may not in compliance with be bypassed in Rod Action

[BPWS]. Control System (RACS) in accordance with SR 3.3.2.1.8.

Move associated control 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> rod(s) to correct position.

OR A.2 Declare associated control 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> rod(s) inoperable.

B. Nine or more B.1 ---------------NOTE--------------

OPERABLE control rods Affected control rods may not in compliance with be bypassed in RACS in

[BPWS]. accordance with SR 3.3.2.1.8 for insertion only.

Suspend withdrawal of Immediately control rods.

AND General Electric BWR/6 STS 3.1.6-1 Rev. 5.0

Rod Pattern Control 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply with [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[BPWS].

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.1.6-2 Rev. 5.0

SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [ Concentration of boron A.1 Restore concentration of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ]

in solution not within boron in solution to within limits but > [ ]. limits.

B. One SLC subsystem B.1 Restore SLC subsystem to 7 days inoperable [for reasons OPERABLE status.

other than Condition A]. [OR In accordance with the Risk Informed Completion Time Program]

C. Two SLC subsystems C.1 Restore one SLC 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> inoperable [for reasons subsystem to OPERABLE other than Condition A]. status.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

General Electric BWR/6 STS 3.1.7-1 Rev. 5.0

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium pentaborate [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> solution is [ [4530] gallons].

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.7.2 [ Verify temperature of sodium pentaborate solution [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> is within the limits of [Figure 3.1.7-1].

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.1.7.3 [ Verify temperature of pump suction piping is within [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> the limits of [Figure 3.1.7-1].

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.1.7.4 Verify continuity of explosive charge. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.1.7-2 Rev. 5.0

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify the concentration of boron in solution is [ 31 days

[within the limits of Figure 3.1.7-1].

OR In accordance with the Surveillance Frequency Control Program ]

AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after water or boron is added to solution AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of

[Figure 3.1.7-1]

SR 3.1.7.6 Verify each SLC subsystem manual, power [ 31 days operated, [and automatic valve] in the flow path that is not locked, sealed, or otherwise secured in OR position is in the correct position, or can be aligned to the correct position. In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.1.7-3 Rev. 5.0

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.7 Verify each pump develops a flow rate [41.2] gpm [ In accordance at a discharge pressure [1300] psig. with the INSERVICE TESTING PROGRAM OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.7.8 Verify flow through one SLC subsystem from pump [ [18] months on a into reactor pressure vessel. STAGGERED TEST BASIS OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.1.7-4 Rev. 5.0

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.9 [ Verify all heat traced piping between storage tank [ [18] months and pump suction is unblocked.

AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of

[Figure 3.1.7-1]

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.1.7.10 [ Verify sodium pentaborate enrichment is Prior to addition to

[60.0] atom percent B-10. SLC tank ]

General Electric BWR/6 STS 3.1.7-5 Rev. 5.0

SLC System 3.1.7 General Electric BWR/6 STS 3.1.7-6 Rev. 5.0

SDV Vent and Drain Valves 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves LCO 3.1.8 Each SDV vent and drain valve shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

1. Separate Condition entry is allowed for each SDV vent and drain line.

2. An isolated line may be unisolated under administrative control to allow draining and venting of the SDV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SDV vent A.1 Isolate the associated line. 7 days or drain lines with one valve inoperable.

B. One or more SDV vent B.1 Isolate the associated line. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or drain lines with both valves inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

General Electric BWR/6 STS 3.1.8-1 Rev. 5.0

SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 -------------------------------NOTE------------------------------

Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.

Verify each SDV vent and drain valve is open. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully [ 92 days closed and fully open position.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.1.8.3 Verify each SDV vent and drain valve: [ [18] months

a. Closes in [30] seconds after receipt of an OR actual or simulated scram signal and In accordance

b. Opens when the actual or simulated scram with the signal is reset. Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.1.8-2 Rev. 5.0

APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limits. within limits.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to < 25% RTP.

Time not met.

General Electric BWR/6 STS 3.2.1-1 Rev. 5.0

APLHGR 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal to the Once within limits specified in the COLR. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 25% RTP AND

[ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.2.1-2 Rev. 5.0

MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limits. limits.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to < 25% RTP.

Time not met.

General Electric BWR/6 STS 3.2.2-1 Rev. 5.0

MCPR 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the Once within limits specified in the COLR. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 25% RTP AND

[ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.2.2-2 Rev. 5.0

LHGR (Optional) 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) (Optional)

LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within A.1 Restore LHGR(s) to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limits. limits.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits Once within specified in the COLR. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 25% RTP AND

[ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.2.3-1 Rev. 5.0

APRM Gain and Setpoints (Optional) 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Average Power Range Monitor (APRM) Gain and Setpoints (Optional)

LCO 3.2.4 a. MFLPD shall be less than or equal to Fraction of RTP, or

b. Each required APRM setpoint specified in the COLR shall be made applicable, or

c. Each required APRM gain shall be adjusted such that the APRM readings are 100% times MFLPD.

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the requirements of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> LCO not met. the LCO.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to < 25% RTP.

Time not met.

General Electric BWR/6 STS 3.2.4-1 Rev. 5.0

APRM Gain and Setpoints (Optional) 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 -------------------------------NOTE------------------------------

Not required to be met if SR 3.2.4.2 is satisfied for LCO 3.2.4 Item b or c requirements.

Verify MFLPD is within limits. Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 25% RTP AND

[ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter OR In accordance with the Surveillance Frequency Control Program ]

SR 3.2.4.2 -------------------------------NOTE------------------------------

Not required to be met if SR 3.2.4.1 is satisfied for LCO 3.2.4 Item a requirements.

Verify APRM setpoints or gains are adjusted for the [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> calculated MFLPD.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.2.4-2 Rev. 5.0

RPS Instrumentation 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation LCO 3.3.1.1 The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.1-1.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> channels inoperable.

[OR In accordance with the Risk Informed Completion Time Program]

OR A.2 Place associated trip 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> system in trip.

[OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.3.1.1-1 Rev. 5.0

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more Functions B.1 Place channel in one trip 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> with one or more system in trip.

required channels [OR inoperable in both trip systems. In accordance with the Risk Informed Completion Time Program]

OR B.2 Place one trip system in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> trip.

[OR In accordance with the Risk Informed Completion Time Program]

C. One or more Functions C.1 Restore RPS trip capability. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> with RPS trip capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, B, Table 3.3.1.1-1 for the or C not met. channel.

E. As required by Required E.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Action D.1 and POWER to < [40]% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Action D.1 and POWER to < 25% RTP.

referenced in Table 3.3.1.1-1.

General Electric BWR/6 STS 3.3.1.1-2 Rev. 5.0

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. As required by Required G.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by Required H.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action D.1 and referenced in Table 3.3.1.1-1.

I. As required by Required I.1 Initiate action to fully insert Immediately Action D.1 and all insertable control rods in referenced in core cells containing one or Table 3.3.1.1-1. more fuel assemblies.

SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.1-3 Rev. 5.0

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.2 -------------------------------NOTE------------------------------

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

Compare the average power range monitor (APRM) [ 7 days channels to the calculated power. Adjust the APRM channels if the calculated power exceeds the APRM OR output by more than 2% RTP while operating at 25% RTP. In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.3 Adjust the channel to conform to a calibrated flow [ 7 days signal.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.4 -------------------------------NOTE------------------------------

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. [ 7 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.1-4 Rev. 5.0

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. [ 7 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.6 Calibrate the local power range monitors. [ 1000 MWD/T average core exposure OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.7 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.8 [ Calibrate the trip units. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.1.1-5 Rev. 5.0

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.9 ------------------------------NOTES-----------------------------

1. Neutron detectors are excluded.

2. For function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.

Perform CHANNEL CALIBRATION. [ 184 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.10 Perform CHANNEL FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.1-6 Rev. 5.0

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.11 ------------------------------NOTES-----------------------------

1. Neutron detectors are excluded.

2. For function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.

Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.12 Verify the APRM Flow Biased Simulated Thermal [ [18] months Power - High time constant is [7] seconds.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.1-7 Rev. 5.0

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.13 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.14 Verify Turbine Stop Valve Closure, Trip Oil Pressure [ [18] months

- Low and Turbine Control Valve Fast Closure Trip Oil Pressure - Low Functions are not bypassed OR when THERMAL POWER is [40]% RTP.

In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.1.15 -----------------------------NOTE[S]----------------------------

1. Neutron detectors are excluded.

[ 2. For Function 6, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. ]

Verify the RPS RESPONSE TIME is within limits. [ [18] months on a STAGGERED TEST BASIS OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.1-8 Rev. 5.0

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 5)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

1. Intermediate Range Monitors

a. Neutron Flux - High 2 [3] H SR 3.3.1.1.1 [122/125]

SR 3.3.1.1.4 divisions of full SR 3.3.1.1.11(a)(b) scale SR 3.3.1.1.13 5(c) [3] I SR 3.3.1.1.1 [122/125]

SR 3.3.1.1.5 divisions of full SR 3.3.1.1.11(a)(b) scale SR 3.3.1.1.13

b. Inop 2 [3] H SR 3.3.1.1.4 NA SR 3.3.1.1.13 5(c) [3] I SR 3.3.1.1.5 NA SR 3.3.1.1.13

2. Average Power Range Monitors

a. Neutron Flux - High, 2 [3] H SR 3.3.1.1.1 [20]% RTP Setdown SR 3.3.1.1.4 SR 3.3.1.1.6 SR 3.3.1.1.9(a)(b)

SR 3.3.1.1.13 (a) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(b) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

(c) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

General Electric BWR/6 STS 3.3.1.1-9 Rev. 5.0

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 5)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

2. Average Power Range Monitors (Continued)

b. Flow Biased 1 [3] G SR 3.3.1.1.1 [0.66 W +

Simulated Thermal SR 3.3.1.1.2 67]% RTP Power - High SR 3.3.1.1.3 and [113]%

SR 3.3.1.1.6 RTP[(d)]

SR 3.3.1.1.7 SR 3.3.1.1.9(a)(b)

SR 3.3.1.1.12(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.15

c. Fixed Neutron Flux - 1 [3] G SR 3.3.1.1.1 [120]% RTP High SR 3.3.1.1.2 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.9(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.15

d. Inop 1,2 [3] H SR 3.3.1.1.6 NA SR 3.3.1.1.7 SR 3.3.1.1.13

3. Reactor Vessel Steam 1,2 [2] H SR 3.3.1.1.1 [1079.7] psig Dome Pressure - High SR 3.3.1.1.7

[SR 3.3.1.1.8](a)(b)

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.15 (a) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(b) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

[ (d) Allowable Value is [ 0.66 W + 43%] RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating." ]

General Electric BWR/6 STS 3.3.1.1-10 Rev. 5.0

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 3 of 5)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

4. Reactor Vessel Water 1,2 [2] H SR 3.3.1.1.1 [10.8] inches Level - Low, Level 3 SR 3.3.1.1.7

[SR 3.3.1.1.8](a)(b)

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.15

5. Reactor Vessel Water 25% RTP [2] F SR 3.3.1.1.1 [54.1] inches Level - High, Level 8 SR 3.3.1.1.7

[SR 3.3.1.1.8](a)(b)

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.15

6. Main Steam Isolation 1 [8] G SR 3.3.1.1.9 [7]% closed Valve - Closure SR 3.3.1.1.11 SR 3.3.1.1.13 SR 3.3.1.1.15

7. Drywell Pressure - High 1,2 [2] H SR 3.3.1.1.1 [1.43] psig SR 3.3.1.1.7

[SR 3.3.1.1.8](a)(b)

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 (a) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(b) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

General Electric BWR/6 STS 3.3.1.1-11 Rev. 5.0

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 4 of 5)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

8. Scram Discharge Volume Water Level -

High

a. Transmitter/Trip Unit 1,2 [2] H SR 3.3.1.1.1 [63]% of full SR 3.3.1.1.7 scale

[SR 3.3.1.1.8](a)(b)

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 5(c) [2] I SR 3.3.1.1.1 [63]% of full SR 3.3.1.1.7 scale

[SR 3.3.1.1.8](a)(b)

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13

b. Float Switch 1,2 [2] H SR 3.3.1.1.7 [65] inches SR 3.3.1.1.11 SR 3.3.1.1.13 5(c) [2] I SR 3.3.1.1.7 [65] inches SR 3.3.1.1.11 SR 3.3.1.1.13

9. Turbine Stop Valve [40]% RTP [4] E SR 3.3.1.1.7 [37] psig Closure, Trip Oil [SR 3.3.1.1.8](a)(b)

Pressure - Low SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15

10. Turbine Control Valve [40]% RTP [2] E SR 3.3.1.1.7 [42] psig Fast Closure, Trip Oil [SR 3.3.1.1.8](a)(b)

Pressure - Low SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 (a) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(b) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

(c) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

General Electric BWR/6 STS 3.3.1.1-12 Rev. 5.0

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 5 of 5)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

11. Reactor Mode Switch - 1,2 [2] H SR 3.3.1.1.10 NA Shutdown Position SR 3.3.1.1.13 5(c) [2] I SR 3.3.1.1.10 NA SR 3.3.1.1.13

12. Manual Scram 1,2 [2] H SR 3.3.1.1.5 NA SR 3.3.1.1.13 5(c) [2] I SR 3.3.1.1.5 NA SR 3.3.1.1.13 (c) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

General Electric BWR/6 STS 3.3.1.1-13 Rev. 5.0

SRM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION 3.3.1.2 Source Range Monitor (SRM) Instrumentation LCO 3.3.1.2 The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.2-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required SRMs to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> SRMs inoperable in OPERABLE status.

MODE 2 with [OR intermediate range monitors (IRMs) on In accordance with Range 2 or below. the Risk Informed Completion Time Program]

B. [Four] required SRMs B.1 Suspend control rod Immediately inoperable in MODE 2 withdrawal.

with IRMs on Range 2 or below.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A or B not met.

D. One or more required D.1 Fully insert all insertable 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> SRMs inoperable in control rods.

MODE 3 or 4.

AND D.2 Place reactor mode switch 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> in the shutdown position.

General Electric BWR/6 STS 3.3.1.2-1 Rev. 5.0

SRM Instrumentation 3.3.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more required E.1 Suspend CORE Immediately SRMs inoperable in ALTERATIONS except for MODE 5. control rod insertion.

AND E.2 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS

---

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

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.

SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.2-2 Rev. 5.0

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.2 ------------------------------NOTES-----------------------------

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is located in: [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

a. The fueled region, OR

b. The core quadrant where CORE In accordance ALTERATIONS are being performed when the with the associated SRM is included in the fueled Surveillance region, and Frequency Control Program ]

c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.

SR 3.3.1.2.3 Perform CHANNEL CHECK. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.2-3 Rev. 5.0

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.4 -------------------------------NOTE------------------------------

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Verify count rate is: [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during CORE

a. [3.0] cps with a signal to noise ratio [2:1] or ALTERATIONS

b. [0.7] cps with a signal to noise ratio [20:1]. AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST [and [ 7 days determination of signal to noise ratio].

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.2-4 Rev. 5.0

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.6 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below.

Perform CHANNEL FUNCTIONAL TEST [and [ 31 days determination of signal to noise ratio].

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.1.2.7 ------------------------------NOTES-----------------------------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.1.2-5 Rev. 5.0

SRM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS REQUIREMENTS

1. Source Range Monitor 2(a) [4] SR 3.3.1.2.1 SR 3.3.1.2.4 SR 3.3.1.2.6 SR 3.3.1.2.7 3,4 2 SR 3.3.1.2.3 SR 3.3.1.2.4 SR 3.3.1.2.6 SR 3.3.1.2.7 5 2(b), (c) SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.7 (a) With IRMs on Range 2 or below.

(b) Only one SRM channel is required to be OPERABLE during spiral offload or reload when the fueled region includes only that SRM detector.

(c) Special movable detectors may be used in place of SRMs if connected to normal SRM circuits.

General Electric BWR/6 STS 3.3.1.2-6 Rev. 5.0

Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod A.1 Suspend control rod Immediately withdrawal limiter (RWL) withdrawal.

channels inoperable.

B. One or more rod pattern B.1 Suspend control rod Immediately controller channels movement except by inoperable. scram.

C. One or more Reactor C.1 Suspend control rod Immediately Mode Switch - Shutdown withdrawal.

Position channels inoperable. AND C.2 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies.

General Electric BWR/6 STS 3.3.2.1-1 Rev. 5.0

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.

2. When an RWL channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is > [70]% RTP.

Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.2.1.2 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is > 35% RTP and 70% RTP.

Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.2.1-2 Rev. 5.0

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.1.3 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn at [10]% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.2.1.4 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is [10]% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.2.1.5 Calibrate the trip unit. [ 92 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.2.1-3 Rev. 5.0

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.1.6 Verify the RWL high power Function is not bypassed [ 92 days when THERMAL POWER is > [70]% RTP.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.2.1.7 Perform CHANNEL CALIBRATION. The Allowable [ 184 days Value shall be:

OR

a. Low power setpoint, > [10]% RTP and

[35]% RTP and In accordance with the

b. High power setpoint, [70]% RTP. Surveillance Frequency Control Program ]

SR 3.3.2.1.8 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.2.1.9 Verify the bypassing and movement of control rods Prior to and required to be bypassed in Rod Action Control during the System (RACS) by a second licensed operator or movement of other qualified member of the technical staff. control rods bypassed in RACS General Electric BWR/6 STS 3.3.2.1-4 Rev. 5.0

Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS REQUIREMENTS

1. Rod Pattern Control System

a. Rod withdrawal limiter [(a)] 2 SR 3.3.2.1.1 SR 3.3.2.1.6 SR 3.3.2.1.7(b)(c)

[(d)] 2 SR 3.3.2.1.2 SR 3.3.2.1.5(b)(c)

SR 3.3.2.1.7(b)(c)

b. Rod pattern controller 1(e), 2(e) 2 SR 3.3.2.1.3 SR 3.3.2.1.4 SR 3.3.2.1.5 SR 3.3.2.1.7 SR 3.3.2.1.9

2. Reactor Mode Switch - Shutdown Position (f) 2 SR 3.3.2.1.8 (a) THERMAL POWER > [70]% RTP.

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

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures Nominal [Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

(d) THERMAL POWER > [35]% RTP and [70]% RTP.

(e) With THERMAL POWER [10]% RTP [, except during the reactor shutdown process if the coupling of each withdrawn control rod has been confirmed].

(f) Reactor mode switch in the shutdown position.

General Electric BWR/6 STS 3.3.2.1-5 Rev. 5.0

PAM Instrumentation 3.3.3.1 3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3.1 The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

Separate Condition entry is allowed for each Function.

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

channel inoperable.

B. Required Action and B.1 Initiate action in accordance Immediately associated Completion with Specification 5.6.5.

Time of Condition A not met.

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

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C not Table 3.3.3.1-1 for the met. channel.

General Electric BWR/6 STS 3.3.3.1-1 Rev. 5.0

PAM Instrumentation 3.3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action D.1 and referenced in Table 3.3.3.1-1.

F. [ As required by F.1 Initiate action in accordance Immediately ]

Required Action D.1 and with Specification 5.6.5.

referenced in Table 3.3.3.1-1.

SURVEILLANCE REQUIREMENTS

---

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

These SRs apply to each Function in Table 3.3.3.1-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.3.1.2 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.3.1-2 Rev. 5.0

PAM Instrumentation 3.3.3.1 Table 3.3.3.1-1 (page 1 of 1)

Post Accident Monitoring Instrumentation CONDITIONS REFERENCED FROM REQUIRED REQUIRED FUNCTION CHANNELS ACTION D.1

1. Reactor Steam Dome Pressure 2 E

2. Reactor Vessel Water Level 2 E

3. Suppression Pool Water Level 2 E

4. Drywell Pressure 2 E

5. Primary Containment Area Radiation 2 [F]

[ 6. Drywell Sump Level 2 E]

[ 7. Drywell Drain Sump Level 2 E]

8. Penetration Flow Path PCIV Position 2 per penetration flow E path(a) (c)

9. Wide Range Neutron Flux 2 E

10. Primary Containment Pressure 2 E

11. [Relief Valve Discharge Location] Suppression Pool 2(c) E Water Temperature (a) Not required for isolation valves whose associated penetration flow path is isolated by at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

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

(c) Monitoring each [relief valve discharge location].

---

REVIEWER'S NOTE---------------------------------------------------------------

Table 3.3.3.1-1 shall be amended for each plant as necessary to list:

1. All Regulatory Guide 1.97, Type A instruments and

2. All Regulatory Guide 1.97, Category 1, non-Type A instruments specified in the plant's Regulatory Guide 1.97, Safety Evaluation Report.

General Electric BWR/6 STS 3.3.3.1-3 Rev. 5.0

Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30 days Functions inoperable. to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.2.1 [ Perform CHANNEL CHECK for each required [ 31 days instrumentation channel that is normally energized.

OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.3.2-1 Rev. 5.0

Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.3.2.2 Verify each required control circuit and transfer [ [18] months switch is capable of performing the intended functions. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each [ [18] months required instrumentation channel.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.3.2-2 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.1 a. Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE:

1. Turbine Stop Valve (TSV) Closure, Trip Oil Pressure - Low and

2. Turbine Control Valve (TCV) Fast Closure, Trip Oil Pressure -

Low.

[ OR

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for inoperable EOC-RPT as specified in the COLR are made applicable. ]

APPLICABILITY: THERMAL POWER [40]% RTP with any recirculation pump in fast speed.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore channel to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> channels inoperable. OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

OR General Electric BWR/6 STS 3.3.4.1-1 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 ---------------NOTE--------------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />

[OR In accordance with the Risk Informed Completion Time Program]

B. One or more Functions B.1 Restore EOC-RPT trip 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> with EOC-RPT trip capability.

capability not maintained. OR AND [ B.2 Apply the MCPR limit for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ]

inoperable EOC-RPT as

[MCPR limit for specified in the COLR.

inoperable EOC-RPT not made applicable.]

C. Required Action and C.1 Remove the associated 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion recirculation pump fast Time not met. speed breaker from service.

OR C.2 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> POWER to < [40]% RTP.

General Electric BWR/6 STS 3.3.4.1-2 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS

---

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

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains EOC-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.4.1-3 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.1.2 ------------------------------NOTES-----------------------------

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

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the LTS] are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures

[Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and the as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

[ Calibrate the trip units. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.4.1-4 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.1.3 ------------------------------NOTES-----------------------------

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

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures

[Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and the as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

Perform CHANNEL CALIBRATION. The Allowable [ [18] months Values shall be:

OR

a. TSV Closure, Trip Oil Pressure - Low:

[37] psig and In accordance with the

b. TCV Fast Closure, Trip Oil Pressure - Surveillance Low: [42] psig. Frequency Control Program ]

General Electric BWR/6 STS 3.3.4.1-5 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, [ [18] months including breaker actuation.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.4.1.5 Verify TSV Closure, Trip Oil Pressure - Low and [ [18] months TCV Fast Closure, Trip Oil Pressure - Low Functions are not bypassed when THERMAL OR POWER is [40]% RTP.

In accordance with the Surveillance Frequency Control Program ]

SR 3.3.4.1.6 -------------------------------NOTE------------------------------

Breaker [interruption] time may be assumed from the most recent performance of SR 3.3.4.1.7.

Verify the EOC-RPT SYSTEM RESPONSE TIME is [ [18] months on a within limits. STAGGERED TEST BASIS OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.4.1-6 Rev. 5.0

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.1.7 Determine RPT breaker [interruption] time. [ 60 months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.4.1-7 Rev. 5.0

ATWS-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT)

Instrumentation LCO 3.3.4.2 Two channels per trip system for each ATWS-RPT instrumentation Function listed below shall be OPERABLE:

a. Reactor Vessel Water Level - Low Low, Level 2 and

b. Reactor Steam Dome Pressure - High.

APPLICABILITY: MODE 1.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 14 days inoperable. OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

OR General Electric BWR/6 STS 3.3.4.2-1 Rev. 5.0

ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 ---------------NOTE--------------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in trip. 14 days

[OR In accordance with the Risk Informed Completion Time Program]

B. One Function with B.1 Restore ATWS-RPT trip 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ATWS-RPT trip capability.

capability not maintained.

C. Both Functions with C.1 Restore ATWS-RPT trip 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ATWS-RPT trip capability for one Function.

capability not maintained.

D. Required Action and D.1 ---------------NOTE--------------

associated Completion Only applicable if Time not met. inoperable channel is the result of an inoperable RPT breaker.

Remove the affected 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> recirculation pump from service.

OR D.2 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> General Electric BWR/6 STS 3.3.4.2-2 Rev. 5.0

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS

---

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

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains ATWS-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 [ Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.4.2.3 [ Calibrate the trip units. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.4.2-3 Rev. 5.0

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable [ [18] months Values shall be:

OR

a. Reactor Vessel Water Level - Low Low, Level 2:

[-43.8] inches and In accordance with the

b. Reactor Steam Dome Pressure - High: Surveillance

[1102] psig. Frequency Control Program ]

SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, [ [18] months including breaker actuation.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.4.2-4 Rev. 5.0

ECCS Instrumentation 3.3.5.1 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation LCO 3.3.5.1 The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.1-1.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.1-1 for the channel.

B. As required by Required B.1 --------------NOTE---------------

Action A.1 and Only applicable for referenced in Functions 1.a, 1.b, 2.a Table 3.3.5.1-1. and 2.b.

Declare supported 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery feature(s) inoperable when of loss of initiation its redundant feature ECCS capability for initiation capability is feature(s) in both inoperable. divisions AND General Electric BWR/6 STS 3.3.5.1-1 Rev. 5.0

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2 --------------NOTE---------------

Only applicable for Functions 3.a and 3.b.

Declare High Pressure 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Core Spray (HPCS) System of loss of HPCS inoperable. initiation capability AND B.3 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[OR In accordance with the Risk Informed Completion Time Program]

C. As required by Required C.1 --------------NOTE---------------

Action A.1 and Only applicable for referenced in Functions 1.c, 1.d, 2.c, Table 3.3.5.1-1. and 2.d.

Declare supported 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery feature(s) inoperable when of loss of initiation its redundant feature ECCS capability for initiation capability is feature(s) in both inoperable. divisions AND General Electric BWR/6 STS 3.3.5.1-2 Rev. 5.0

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.2 Restore channel to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

D. As required by Required D.1 ---------------NOTE--------------

Action A.1 and Only applicable if HPCS referenced in pump suction is not aligned Table 3.3.5.1-1. to the suppression pool.

Declare HPCS System 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery inoperable. of loss of HPCS initiation capability AND D.2.1 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[OR In accordance with the Risk Informed Completion Time Program]

OR D.2.2 Align the HPCS pump 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> suction to the suppression pool.

General Electric BWR/6 STS 3.3.5.1-3 Rev. 5.0

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 --------------NOTE---------------

Action A.1 and Only applicable for referenced in Functions 1.e, 1.f, and 2.e.

Table 3.3.5.1-1. -------------------------------------

Declare supported 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery feature(s) inoperable when of loss of initiation its redundant feature ECCS capability for initiation capability is feature(s) in both inoperable. divisions AND E.2 Restore channel to 7 days OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

F. As required by Required F.1 Declare Automatic 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Action A.1 and Depressurization System of loss of ADS referenced in (ADS) valves inoperable. initiation capability in Table 3.3.5.1-1. both trip systems AND General Electric BWR/6 STS 3.3.5.1-4 Rev. 5.0

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F.2 Place channel in trip. 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> [or in accordance with the Risk Informed Completion Time Program] from discovery of inoperable channel concurrent with HPCS or reactor core isolation cooling (RCIC) inoperable AND 8 days

[OR In accordance with the Risk Informed Completion Time Program]

G. As required by Required G.1 ---------------NOTE--------------

Action A.1 and Only applicable for referenced in Functions 4.c, 4.e, 4.f, 4.g, Table 3.3.5.1-1. 5.c, 5.e, and 5.f.

Declare ADS valves 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery inoperable. of loss of ADS initiation capability in both trip systems AND General Electric BWR/6 STS 3.3.5.1-5 Rev. 5.0

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G.2 Restore channel to 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> [or in OPERABLE status. accordance with the Risk Informed Completion Time Program] from discovery of inoperable channel concurrent with HPCS or RCIC inoperable AND 8 days

[OR In accordance with the Risk Informed Completion Time Program]

H. Required Action and H.1 Declare associated Immediately associated Completion supported feature(s)

Time of Condition B, C, inoperable.

D, E, F, or G not met.

General Electric BWR/6 STS 3.3.5.1-6 Rev. 5.0

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than 3.c, 3.f, 3.g, and 3.h, provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.5.1-7 Rev. 5.0

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.5.1.3 [ Calibrate the trip unit. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.5.1.4 [ Perform CHANNEL CALIBRATION. [ 92 days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.5.1.5 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.5.1-8 Rev. 5.0

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.5.1.7 Verify the ECCS RESPONSE TIME is within limits. [ [18] months on a STAGGERED TEST BASIS OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.5.1-9 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)

Subsystems

a. Reactor Vessel 1, 2, 3 [2](a) B SR 3.3.5.1.1 [-152.5]

Water Level - Low SR 3.3.5.1.2 inches Low Low, Level 1 [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 SR 3.3.5.1.7

b. Drywell Pressure - 1, 2, 3 [2](a) B SR 3.3.5.1.1 [1.44] psig High SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 SR 3.3.5.1.7

c. LPCI Pump A Start - 1, 2, 3 [1] C SR 3.3.5.1.2 [ ] seconds Time Delay Relay [SR 3.3.5.1.4] and [5.25]

SR 3.3.5.1.6 seconds (a) Also required to initiate the associated [Technical Specifications (TS) required functions].

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

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

General Electric BWR/6 STS 3.3.5.1-10 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. LPCI and LPCS Subsystems

d. Reactor Steam 1, 2, 3 [3] C SR 3.3.5.1.1 [452] psig Dome Pressure - SR 3.3.5.1.2 and Low (Injection [SR 3.3.5.1.3] [534] psig Permissive) SR 3.3.5.1.5 SR 3.3.5.1.6 SR 3.3.5.1.7

e. [ LPCS Pump Discharge Flow - 1, 2, 3 [1] E SR 3.3.5.1.1 [ ] gpm and Low (Bypass) ] SR 3.3.5.1.2 [ ] gpm

[SR 3.3.5.1.3]

SR 3.3.5.1.5 SR 3.3.5.1.6

f. [ LPCI Pump A 1, 2, 3 [1] E SR 3.3.5.1.1 [ ] gpm and Discharge Flow - SR 3.3.5.1.2 [ ] gpm Low (Bypass) ] [SR 3.3.5.1.3]

SR 3.3.5.1.5 SR 3.3.5.1.6

[ g. Manual Initiation 1, 2, 3 [1] C SR 3.3.5.1.6 NA ]

General Electric BWR/6 STS 3.3.5.1-11 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel 1, 2, 3 [2](a) B SR 3.3.5.1.1 [-152.5]

Water Level - Low SR 3.3.5.1.2 inches Low Low, Level 1 [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 SR 3.3.5.1.7

b. Drywell Pressure - 1, 2, 3 [2](a) B SR 3.3.5.1.1 [1.44] psig High SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 SR 3.3.5.1.7

c. LPCI Pump B Start - 1, 2, 3 [1] C SR 3.3.5.1.2 [ ] seconds Time Delay Relay SR 3.3.5.1.4 and SR 3.3.5.1.6 [5.25]

seconds

d. Reactor Steam 1, 2, 3 [3] C SR 3.3.5.1.1 [452] psig Dome Pressure - SR 3.3.5.1.2 and Low (Injection [SR 3.3.5.1.3] [534] psig Permissive) SR 3.3.5.1.5 SR 3.3.5.1.6 SR 3.3.5.1.7 (a) Also required to initiate the associated [Technical Specifications (TS) required functions].

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

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

General Electric BWR/6 STS 3.3.5.1-12 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCI B and LPCI C Subsystems

e. [ LPCI Pump B 1, 2, 3 [2] E SR 3.3.5.1.1 [ ] gpm and LPCI Pump C [1 per SR 3.3.5.1.2 and Discharge Flow - pump] [SR 3.3.5.1.3] [ ] gpm Low (Bypass) ] SR 3.3.5.1.5 SR 3.3.5.1.6

[ f. Manual Initiation 1, 2, 3 [1] C SR 3.3.5.1.6 NA ]

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel 1, 2, 3 [4](a) B SR 3.3.5.1.1 [-43.8] inches Water Level - Low SR 3.3.5.1.2 Low, Level 2 [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 SR 3.3.5.1.7

b. Drywell Pressure - 1, 2, 3 [4](a) B SR 3.3.5.1.1 [1.44] psig High SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 SR 3.3.5.1.7 (a) Also required to initiate the associated [TS required functions].

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

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

General Electric BWR/6 STS 3.3.5.1-13 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

3. HPCS System

c. Reactor Vessel 1, 2, 3 [2] C SR 3.3.5.1.1 [55.7] inches Water Level - High, SR 3.3.5.1.2 Level 8 [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

d. Condensate Storage 1, 2, 3 [2] D SR 3.3.5.1.1 [-3] inches Tank Level - Low SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

e. Suppression Pool 1, 2, 3 [2] D SR 3.3.5.1.1 [7.0] inches Water Level - High SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

f. [ HPCS Pump 1, 2, 3 [1] E SR 3.3.5.1.1 [ ] psig Discharge Pressure SR 3.3.5.1.2

- High (Bypass) ] [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

g. [ HPCS System 1, 2, 3 [1] E SR 3.3.5.1.1 [ ] gpm and Flow Rate - Low SR 3.3.5.1.2 [ ] gpm (Bypass) ] [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 (b) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

General Electric BWR/6 STS 3.3.5.1-14 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 6 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

3. HPCS System

[ h. Manual Initiation 1, 2, 3 [1] C SR 3.3.5.1.6 NA ]

4. ADS Trip System A

a. Reactor Vessel 1, 2(e), 3(e) [2] F SR 3.3.5.1.1 [-152.5]

Water Level - Low SR 3.3.5.1.2 inches Low Low, Level 1 [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

b. Drywell Pressure - 1, 2(e), 3(e) [2] F SR 3.3.5.1.1 [1.44] psig High SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

c. ADS Initiation Timer 1, 2(e), 3(e) [1] G SR 3.3.5.1.2 [117]

[SR 3.3.5.1.4] seconds SR 3.3.5.1.6

d. Reactor Vessel 1, 2(e), 3(e) [1] F SR 3.3.5.1.1 [10.8] inches Water Level - Low, SR 3.3.5.1.2 Level 3 [SR 3.3.5.1.3](b)(c)

(Confirmatory) SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

e. LPCS Pump 1, 2(e), 3(e) [2] G SR 3.3.5.1.1 [125] psig Discharge Pressure SR 3.3.5.1.2 and

- High [SR 3.3.5.1.3](b)(c) [165] psig SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6 (b) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

(e) With reactor steam dome pressure > [150] psig.

General Electric BWR/6 STS 3.3.5.1-15 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 7 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

4. ADS Trip System A

f. LPCI Pump A 1, 2(e), 3(e) [2] G SR 3.3.5.1.1 [115] psig Discharge Pressure SR 3.3.5.1.2 and

- High [SR 3.3.5.1.3] [135] psig SR 3.3.5.1.5 SR 3.3.5.1.6

g. [ ADS Bypass Timer 1, 2(e), 3(e) [2] G SR 3.3.5.1.2 [9.4] minutes (High Drywell [SR 3.3.5.1.4]

Pressure) ] SR 3.3.5.1.6

[ h. Manual Initiation 1, 2(e), 3(e) [2] G SR 3.3.5.1.6 NA ]

5. ADS Trip System B

a. Reactor Vessel 1, 2(e), 3(e) [2] F SR 3.3.5.1.1 [-152.5]

Water Level - Low SR 3.3.5.1.2 inches Low Low, Level 1 [SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

b. Drywell Pressure - 1, 2(e), 3(e) [2] F SR 3.3.5.1.1 [1.44] psig High SR 3.3.5.1.2

[SR 3.3.5.1.3](b)(c)

SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

c. ADS Initiation Timer 1, 2(e), 3(e) [1] G SR 3.3.5.1.2 [117]

[SR 3.3.5.1.4] seconds SR 3.3.5.1.6 (b) If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

(e) With reactor steam dome pressure > [150] psig.

General Electric BWR/6 STS 3.3.5.1-16 Rev. 5.0

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 8 of 8)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

5. ADS Trip System B

d. Reactor Vessel 1, 2(e), 3(e) [1] F SR 3.3.5.1.1 [10.8] inches Water Level - SR 3.3.5.1.2 Low, Level 3 [SR 3.3.5.1.3](b)(c)

(Confirmatory) SR 3.3.5.1.5(b)(c)

SR 3.3.5.1.6

e. LPCI Pumps B & C 1, 2(e), 3(e) [4] G SR 3.3.5.1.1 [115] psig Discharge Pressure [2 per SR 3.3.5.1.2 and

- High pump] [SR 3.3.5.1.3] [135] psig SR 3.3.5.1.5 SR 3.3.5.1.6

f. [ADS Bypass Timer 1, 2(e), 3(e) [2] G SR 3.3.5.1.2 [9.4] minutes (High Drywell [SR 3.3.5.1.4]

Pressure)] SR 3.3.5.1.6

[ g. Manual Initiation 1, 2(e), 3(e) [2] G SR 3.3.5.1.6 NA ]

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

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

(e) With reactor steam dome pressure > [150] psig.

General Electric BWR/6 STS 3.3.5.1-17 Rev. 5.0

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.2-1.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Initiate action to place Immediately inoperable. channel in trip OR A.2.1 Declare associated Immediately penetration flow path(s) incapable of automatic isolation.

AND A.2.2 Initiate action to calculate Immediately DRAIN TIME.

General Electric BWR/6 STS 3.3.5.2-1 Rev. 5.0

RPV Water Inventory Control Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

---

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

These SRs apply to each Function in Table 3.3.5.2-1.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.5.2-2 Rev. 5.0

RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE REQUIRED MODES OR OTHER CHANNELS PER ALLOWABLE FUNCTION SPECIFIED CONDITIONS FUNCTION VALUE

1. RHR System Isolation

a. Reactor Vessel Water Level - (a) [2 in one trip system] [10.8] inches Low, Level 3

2. Reactor Water Cleanup (RWCU)

System Isolation

a. Reactor Vessel Water Level - (a) [2 in one trip system] [-43.8] inches Low Low, Level 2 (a) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME.

General Electric BWR/6 STS 3.3.5.2-3 Rev. 5.0

RCIC System Instrumentation 3.3.5.3 3.3 INSTRUMENTATION 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > [150] psig.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.3-1 for the channel.

B. As required by Required B.1 Declare RCIC System 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Action A.1 and inoperable. of loss of RCIC referenced in initiation capability Table 3.3.5.3-1.

AND B.2 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[OR In accordance with the Risk Informed Completion Time Program]

C. As required by Required C.1 Restore channel to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Action A.1 and OPERABLE status.

referenced in Table 3.3.5.3-1.

General Electric BWR/6 STS 3.3.5.3-1 Rev. 5.0

RCIC System Instrumentation 3.3.5.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required D.1 ---------------NOTE--------------

Action A.1 and Only applicable if RCIC referenced in pump suction is not aligned Table 3.3.5.3-1. to the suppression pool.

Declare RCIC System 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery inoperable. of loss of RCIC initiation capability AND D.2.1 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[OR In accordance with the Risk Informed Completion Time Program]

OR D.2.2 Align RCIC pump suction to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> the suppression pool.

E. Required Action and E.1 Declare RCIC System Immediately associated Completion inoperable.

Time of Condition B, C, or D not met.

General Electric BWR/6 STS 3.3.5.3-2 Rev. 5.0

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.5.3-1 to determine which SRs apply for each RCIC Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 2 and 5; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.5.3.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.5.3.3 [ Calibrate the trip units. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.5.3-3 Rev. 5.0

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.5.3.4 Perform CHANNEL CALIBRATION. [ 18 months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.5.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.5.3-4 Rev. 5.0

RCIC System Instrumentation 3.3.5.3 Table 3.3.5.3-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS PER FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water [4] B SR 3.3.5.3.1 [-43.8] inches Level - Low Low, Level 2 SR 3.3.5.3.2

[SR 3.3.5.3.3](a)(b)

SR 3.3.5.3.4(a)(b)

SR 3.3.5.3.5

2. Reactor Vessel Water [2] C SR 3.3.5.3.1 [55.7] inches Level - High, Level 8 SR 3.3.5.3.2

[SR 3.3.5.3.3](a)(b)

SR 3.3.5.3.4(a)(b)

SR 3.3.5.3.5

3. Condensate Storage Tank [2] D SR 3.3.5.3.1 [-3] inches Level - Low SR 3.3.5.3.2

[SR 3.3.5.3.3](a)(b)

SR 3.3.5.3.4(a)(b)

SR 3.3.5.3.5

[ 4. Suppression Pool Water [2] D SR 3.3.5.3.1 [7.0] inches ]

Level - High SR 3.3.5.3.2

[SR 3.3.5.3.3](a)(b)

SR 3.3.5.3.4(a)(b)

SR 3.3.5.3.5

[ 5. Manual Initiation [1] C SR 3.3.5.3.5 NA ]

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

(b) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures [Nominal Trip Setpoint] to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

General Electric BWR/6 STS 3.3.5.3-5 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.1-1.

ACTIONS

---

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

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for channels inoperable. Functions 2.b, 5.c, 5.d, and 5.e

[OR In accordance with the Risk Informed Completion Time Program]

AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for Functions other than Functions 2.b, 5.c, 5.d, and 5.e

[OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.3.6.1-1 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more automatic B.1 Restore isolation capability. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Functions with isolation capability not maintained.

C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A or B Table 3.3.6.1-1 for the not met. channel.

D. As required by Required D.1 Isolate associated main 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action C.1 and steam line (MSL).

referenced in Table 3.3.6.1-1. OR D.2.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND D.2.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E. As required by Required E.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action C.1 and referenced in Table 3.3.6.1-1.

F. As required by Required F.1 Isolate the affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Action C.1 and penetration flow path(s).

referenced in Table 3.3.6.1-1.

G. As required by Required G.1 Isolate the affected 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Action C.1 and penetration flow path(s).

referenced in Table 3.3.6.1-1.

General Electric BWR/6 STS 3.3.6.1-2 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Action C.1 and referenced in AND Table 3.3.6.1-1.

H.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Required Action and associated Completion Time of Condition F or G not met.

I. As required by Required I.1 Declare associated standby 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Action C.1 and liquid control subsystem referenced in inoperable.

Table 3.3.6.1-1.

OR I.2 Isolate the Reactor Water 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Cleanup System.

J. As required by Required J.1 Initiate action to restore Immediately Action C.1 and channel to OPERABLE referenced in status.

Table 3.3.6.1-1.

K. As required by Required K.1 Isolate the affected Immediately Action C.1 and penetration flow path(s).

referenced in Table 3.3.6.1-1. OR K.2 Suspend movement of Immediately

[recently] irradiated fuel assemblies in the [primary and secondary containment].

General Electric BWR/6 STS 3.3.6.1-3 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.1.3 [ Calibrate the trip unit. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.6.1-4 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. [ 92 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.1-5 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

---

REVIEWERS NOTE---------------------------------

This SR is applied only to Functions of Table 3.3.6.1-1 with required response times not corresponding to DG start time.

SR 3.3.6.1.7 -------------------------------NOTE------------------------------

[ Radiation detectors may be excluded. ]

Verify the ISOLATION SYSTEM RESPONSE TIME [ [18] months on a is within limits. STAGGERED TEST BASIS OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.1-6 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

1. Main Steam Line Isolation

a. Reactor Vessel 1,2,3 [2] D SR 3.3.6.1.1 [-152.5]

Water Level - Low SR 3.3.6.1.2 inches Low Low, Level 1 [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

b. Main Steam Line 1 [2] E SR 3.3.6.1.1 [837] psig Pressure - Low SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

c. Main Steam Line 1,2,3 [2] per D SR 3.3.6.1.1 [176.5] psig Flow - High MSL SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

d. Condenser Vacuum - 1,2(a), [2] D SR 3.3.6.1.1 [8.7] inches Low SR 3.3.6.1.2 Hg vacuum 3(a) [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6

e. Main Steam Tunnel 1,2,3 [2] D SR 3.3.6.1.1 [191]F Temperature - High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Main Steam Tunnel 1,2,3 [2] D SR 3.3.6.1.1 [104]F Differential SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

[ g. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 NA ]

(a) With any turbine [stop valve] not closed.

General Electric BWR/6 STS 3.3.6.1-7 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

2. Primary Containment Isolation

a. Reactor Vessel 1,2,3 [2] H SR 3.3.6.1.1 [-43.8]

Water Level - Low SR 3.3.6.1.2 inches Low, Level 2 [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

b. Drywell Pressure - 1,2,3 [2] H SR 3.3.6.1.1 [1.43] psig High SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

[ c. Reactor Vessel 1,2,3 [2] F SR 3.3.6.1.1 [-152.5]

Water Level - Low SR 3.3.6.1.2 inches ]

Low Low, Level 1 [SR 3.3.6.1.3]

(ECCS Divisions 1 SR 3.3.6.1.5 and 2) SR 3.3.6.1.6 SR 3.3.6.1.7

[ d. Drywell Pressure - 1,2,3 [2] F SR 3.3.6.1.1 [1.44] psig ]

High (ECCS SR 3.3.6.1.2 Divisions 1 and 2) [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

[ e. Reactor Vessel 1,2,3 [4] F SR 3.3.6.1.1 [-43.8]

Water Level - Low SR 3.3.6.1.2 inches ]

Low, Level 2 (HPCS) [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

[ f. Drywell Pressure - 1,2,3 [4] F SR 3.3.6.1.1 [1.44] psig ]

High (HPCS) SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 General Electric BWR/6 STS 3.3.6.1-8 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

2. Primary Containment Isolation

g. Containment and 1,2,3 [2] F SR 3.3.6.1.1 [4.0] mR/hr Drywell Ventilation SR 3.3.6.1.2 Exhaust Radiation- SR 3.3.6.1.5 High SR 3.3.6.1.6 SR 3.3.6.1.7

[(b)] [2] K SR 3.3.6.1.1 [4.0] mR/hr SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

[ h. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 NA ]

3. Reactor Core Isolation Cooling (RCIC) System Isolation

a. RCIC Steam Line 1,2,3 [1] F SR 3.3.6.1.1 [64] inches Flow - High SR 3.3.6.1.2 water

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

[ b. RCIC Steam Line [1,2,3] [1] F SR 3.3.6.1.2 [3] seconds Flow Time Delay SR 3.3.6.1.4 and SR 3.3.6.1.6 [7] seconds ]

c. RCIC Steam Supply 1,2,3 [1] F SR 3.3.6.1.1 [53] psig Line Pressure - Low SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

d. RCIC Turbine 1,2,3 [2] F SR 3.3.6.1.1 [20] psig Exhaust Diaphragm SR 3.3.6.1.2 Pressure - High [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6

[(b) During movement of [recently] irradiated fuel assemblies in [primary or secondary containment.]

General Electric BWR/6 STS 3.3.6.1-9 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

3. RCIC System Isolation

e. RCIC Equipment 1,2,3 [1] F SR 3.3.6.1.1 [191]F Room Ambient SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

f. RCIC Equipment 1,2,3 [1] F SR 3.3.6.1.1 [128]F Room Differential SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

g. Main Steam Line 1,2,3 [1] F SR 3.3.6.1.1 [191]F Tunnel Ambient SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

h. Main Steam Line 1,2,3 [1] F SR 3.3.6.1.1 [104]F Tunnel Differential SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

i. Main Steam Line 1,2,3 [1] F SR 3.3.6.1.2 [30] minutes Tunnel Temperature SR 3.3.6.1.4 Timer SR 3.3.6.1.6

j. RHR Equipment 1,2,3 [1 per F SR 3.3.6.1.1 [171]F Room Ambient room] SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

k. RHR Equipment 1,2,3 [1 per F SR 3.3.6.1.1 [102]F Room Differential room] SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

l. RCIC/RHR Steam 1,2,3 [1] F SR 3.3.6.1.1 [43] inches Line Flow - High SR 3.3.6.1.2 water

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6

m. Drywell Pressure - 1,2,3 [1] F SR 3.3.6.1.1 [1.44] psig High SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 General Electric BWR/6 STS 3.3.6.1-10 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

3. RCIC System Isolation

[ n. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 NA ]

4. Reactor Water Cleanup (RWCU) System Isolation

a. Differential Flow - 1,2,3 [1] F SR 3.3.6.1.1 [89] gpm High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

[SR 3.3.6.1.7]

b. Differential Flow - 1,2,3 [1] F SR 3.3.6.1.2 [57] seconds Timer SR 3.3.6.1.4 SR 3.3.6.1.6

c. RWCU Heat 1,2,3 [1] F SR 3.3.6.1.1 [126]F Exchanger SR 3.3.6.1.2 Equipment Room SR 3.3.6.1.5 Temperature-High SR 3.3.6.1.6

d. RWCU Heat 1,2,3 [1] F SR 3.3.6.1.1 [66]F Exchanger SR 3.3.6.1.2 Equipment Room SR 3.3.6.1.5 Differential SR 3.3.6.1.6 Temperature - High

e. RWCU Pump Rooms 1,2,3 [1] F SR 3.3.6.1.1 [176]F Temperature - High [1 per SR 3.3.6.1.2 room] SR 3.3.6.1.5 SR 3.3.6.1.6

f. RWCU Pump Rooms 1,2,3 [1] F SR 3.3.6.1.1 [118]F Differential [1 per SR 3.3.6.1.2 Temperature - High room] SR 3.3.6.1.5 SR 3.3.6.1.6

g. RWCU Valve Nest 1,2,3 [1] F SR 3.3.6.1.1 [141]F Room Temperature - SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6

h. RWCU Valve Nest 1,2,3 [1] F SR 3.3.6.1.1 [73]F Room Differential SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 General Electric BWR/6 STS 3.3.6.1-11 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 6 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

4. RWCU System Isolation

i. Main Steam Line 1,2,3 [1] F SR 3.3.6.1.1 [191]F Tunnel Ambient SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

j. Main Steam Line 1,2,3 [1] F SR 3.3.6.1.1 [104]F Tunnel Differential SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

k. Reactor Vessel 1,2,3 [2] F SR 3.3.6.1.1 [-43.8]

Water Level - Low SR 3.3.6.1.2 inches Low, Level 2 [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

l. Standby Liquid 1,2 [1] I SR 3.3.6.1.6 NA Control System Initiation

[ m. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 NA ]

5. Shutdown Cooling System Isolation

a. RHR Equipment 2,3 [1 per F SR 3.3.6.1.1 [171]F Room Ambient room] SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

b. RHR Equipment 2,3 [1 per F SR 3.3.6.1.1 [102]F Room Differential room] SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

c. Reactor Vessel 3 [2] J SR 3.3.6.1.1 [10.8] inches Water Level - Low, SR 3.3.6.1.2 Level 3 [SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 General Electric BWR/6 STS 3.3.6.1-12 Rev. 5.0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 7 of 7)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

5. Shutdown Cooling System Isolation

d. Reactor Steam Dome 1,2,3 [2] F SR 3.3.6.1.1 [150] psig Pressure - High SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6

e. Drywell Pressure - 1,2,3 [2] F SR 3.3.6.1.1 [1.43] psig High SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5 SR 3.3.6.1.6 General Electric BWR/6 STS 3.3.6.1-13 Rev. 5.0

Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION 3.3.6.2 Secondary Containment Isolation Instrumentation LCO 3.3.6.2 The secondary containment isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.2-1.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in trip. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for inoperable. Function 2 AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for Functions other than Function 2 B. One or more automatic B.1 Restore secondary 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Functions with containment isolation secondary containment capability.

isolation capability not maintained.

C. Required Action and C.1.1 Isolate the associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> associated Completion penetration flow path(s).

Time of Condition A or B not met. OR C.1.2 Declare associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> secondary containment isolation valves inoperable.

AND General Electric BWR/6 STS 3.3.6.2-1 Rev. 5.0

Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.2.1 Place the associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> standby gas treatment (SGT) subsystem(s) in operation.

OR C.2.2 Declare associated SGT 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> subsystem inoperable.

SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains secondary containment isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.2-2 Rev. 5.0

Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.2.3 [ Calibrate the trip unit. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.2-3 Rev. 5.0

Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

---

REVIEWERS NOTE---------------------------------

This SR is applied only to Functions of Table 3.3.6.2-1 with required response times not corresponding to DG start time.

SR 3.3.6.2.6 -------------------------------NOTE------------------------------

[ Radiation detectors may be excluded. ]

Verify the ISOLATION SYSTEM RESPONSE TIME [ [18] months on a is within limits. STAGGERED TEST BASIS OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.2-4 Rev. 5.0

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation APPLICABLE MODES AND REQUIRED OTHER CHANNELS SPECIFIED PER TRIP SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM REQUIREMENTS VALUE

1. Reactor Vessel Water 1,2,3 [2] SR 3.3.6.2.1 [-43.8] inches Level - Low Low, Level 2 SR 3.3.6.2.2

[SR 3.3.6.2.3]

SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.6

2. Drywell Pressure - High 1,2,3 [2] SR 3.3.6.2.1 [1.43] psig SR 3.3.6.2.2

[SR 3.3.6.2.3]

SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.6

3. Fuel Handling Area 1,2,3,[(a)] [2] SR 3.3.6.2.1 [4.0] mR/hr Ventilation Exhaust SR 3.3.6.2.2 Radiation - High High SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.6

4. Fuel Handling Area Pool 1,2,3,[(a)] [2] SR 3.3.6.2.1 [35] mR/hr Sweep Exhaust Radiation SR 3.3.6.2.2

- High High SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.6

5. [ Manual Initiation 1,2,3,[(a)] [1 per group] SR 3.3.6.2.5 NA ]

(a) During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

General Electric BWR/6 STS 3.3.6.2-5 Rev. 5.0

RHR Containment Spray System Instrumentation 3.3.6.3 3.3 INSTRUMENTATION 3.3.6.3 Residual Heat Removal (RHR) Containment Spray System Instrumentation LCO 3.3.6.3 The RHR Containment Spray System instrumentation for each Function in Table 3.3.6.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.6.3-1 for the channel.

B. As required by Required B.1 Declare associated RHR 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Action A.1 and containment spray of loss of RHR referenced in subsystem inoperable. containment spray Table 3.3.6.3-1. initiation capability in both trip systems AND B.2 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.3.6.3-1 Rev. 5.0

RHR Containment Spray System Instrumentation 3.3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 ---------------NOTE--------------

Action A.1 and Only applicable for referenced in Functions 2 and 4.

Table 3.3.6.3-1. -------------------------------------

Declare associated RHR 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery containment spray of loss of RHR subsystem inoperable. containment spray initiation capability in both trip systems AND C.2 Restore channel to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

D. Required Action and D.1 Declare associated RHR Immediately associated Completion containment spray Time of Condition B or C subsystem inoperable.

not met.

General Electric BWR/6 STS 3.3.6.3-2 Rev. 5.0

RHR Containment Spray System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each RHR Containment Spray System Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains RHR containment spray initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.3-3 Rev. 5.0

RHR Containment Spray System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.3.3 [ Calibrate the trip unit. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.6.3.4 [ Perform CHANNEL CALIBRATION. [ 92 days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.6.3.5 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.3.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.3-4 Rev. 5.0

RHR Containment Spray System Instrumentation 3.3.6.3 Table 3.3.6.3-1 (page 1 of 1)

RHR Containment Spray System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS FROM PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SYSTEM ACTION A.1 REQUIREMENTS VALUE

1. Drywell Pressure - High [2] B SR 3.3.6.3.1 [1.44] psig SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5 SR 3.3.6.3.6

2. Containment Pressure - High [1] C SR 3.3.6.3.1 [8.34] psig SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5 SR 3.3.6.3.6

3. Reactor Vessel Water Level - Low [2] B SR 3.3.6.3.1 [-152.5] inches Low Low, Level 1 SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5 SR 3.3.6.3.6

4. System A and System B Timers [1] C SR 3.3.6.3.2 [10.26] minutes

[SR 3.3.6.3.4] and [11.44]

SR 3.3.6.3.6 minutes

5. [ Manual Initiation [1] C SR 3.3.6.3.6 NA ]

General Electric BWR/6 STS 3.3.6.3-5 Rev. 5.0

SPMU System Instrumentation 3.3.6.4 3.3 INSTRUMENTATION 3.3.6.4 Suppression Pool Makeup (SPMU) System Instrumentation LCO 3.3.6.4 The SPMU System instrumentation for each Function in Table 3.3.6.4-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.6.4-1 for the channel.

B. As required by Required B.1 Declare associated SPMU 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Action A.1 and subsystem inoperable. of loss of SPMU referenced in initiation capability in Table 3.3.6.4-1. both trip systems AND B.2 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> C. As required by Required C.1 ---------------NOTE--------------

Action A.1 and Only applicable for referenced in Functions 3 and 6.

Table 3.3.6.4-1. -------------------------------------

Declare associated SPMU 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery subsystem inoperable. of loss of SPMU initiation capability in both trip systems AND General Electric BWR/6 STS 3.3.6.4-1 Rev. 5.0

SPMU System Instrumentation 3.3.6.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.2 Restore channel to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.

D. Required Action and D.1 Declare associated SPMU Immediately associated Completion subsystem inoperable.

Time of Condition B or C not met.

SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.6.4-1 to determine which SRs apply for each SPMU Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains SPMU initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.4.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.4.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.4-2 Rev. 5.0

SPMU System Instrumentation 3.3.6.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.4.3 [ Calibrate the trip unit. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.6.4.4 [ Perform CHANNEL CALIBRATION. [ 92 days OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.6.4.5 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.6.4.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.4-3 Rev. 5.0

SPMU System Instrumentation 3.3.6.4 Table 3.3.6.4-1 (page 1 of 1)

Suppression Pool Makeup System Instrumentation REQUIRED CONDITIONS CHANNELS REFERENCED PER FROM TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SYSTEM ACTION A.1 REQUIREMENTS VALUE

1. Drywell Pressure - High [2] B SR 3.3.6.4.1 [1.44] psig SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5 SR 3.3.6.4.6

2. Reactor Vessel Water Level - Low [2] B SR 3.3.6.4.1 [-152.5] inches Low Low, Level 1 SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5 SR 3.3.6.4.6

3. Suppression Pool Water Level - [1] C SR 3.3.6.4.1 [17 ft 2 inches]

Low Low SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5 SR 3.3.6.4.6

4. Drywell Pressure - High [2] B SR 3.3.6.4.1 [1.43] psig SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5 SR 3.3.6.4.6

5. Reactor Vessel Water Level - Low [2] B SR 3.3.6.4.1 [-43.8] inches Low, Level 2 SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5 SR 3.3.6.4.6

6. Timer [1] C SR 3.3.6.4.2 [29.5] minutes

[SR 3.3.6.4.4]

SR 3.3.6.4.6

7. [ Manual Initiation [2] C SR 3.3.6.4.6 NA ]

General Electric BWR/6 STS 3.3.6.4-4 Rev. 5.0

Relief and LLS Instrumentation 3.3.6.5 3.3 INSTRUMENTATION 3.3.6.5 Relief and Low-Low Set (LLS) Instrumentation LCO 3.3.6.5 Two relief and LLS instrumentation trip systems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

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

[OR In accordance with the Risk Informed Completion Time Program]

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not AND met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Two trip systems inoperable.

General Electric BWR/6 STS 3.3.6.5-1 Rev. 5.0,

Relief and LLS Instrumentation 3.3.6.5 SURVEILLANCE REQUIREMENTS

---

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

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains LLS or relief initiation capability, as applicable.

SURVEILLANCE FREQUENCY SR 3.3.6.5.1 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.5-2 Rev. 5.0,

Relief and LLS Instrumentation 3.3.6.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.5.2 -------------------------------NOTES----------------------------

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

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the [Limiting Trip Setpoint (LTSP) or Nominal Trip Setpoint (NTSP)] at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the [LTSP or NTSP] are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The [LTSP or NTSP and the] methodologies used to determine the as-found and the as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

[ Calibrate the trip unit. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.6.5-3 Rev. 5.0,

Relief and LLS Instrumentation 3.3.6.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.5.3 -------------------------------NOTES----------------------------

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

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the [Limiting Trip Setpoint (LTSP) or Nominal Trip Setpoint (NTSP)] at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the [LTSP or NTSP] are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The [LTSP or NTSP and the] methodologies used to determine the as-found and the as-left tolerances are specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference].

Perform CHANNEL CALIBRATION . The Allowable [ [18] months Values shall be:

OR

a. Relief Function In accordance Low: [1103 +/- 15 psig] with the Medium: [1113 +/- 15 psig] Surveillance High: [1123 +/- 15 psig] Frequency Control Program ]

b. LLS Function Low open: [1033 +/- 15 psig]

close: [926 +/- 15 psig]

Medium open: [1073 +/- 15 psig]

close [936 +/- 15 psig]

High open: [1113 +/- 15 psig]

close: [946 +/- 15 psig]

General Electric BWR/6 STS 3.3.6.5-4 Rev. 5.0,

Relief and LLS Instrumentation 3.3.6.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.5.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.6.5-5 Rev. 5.0,

[CRFA] System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 [Control Room Fresh Air (CRFA)] System Instrumentation LCO 3.3.7.1 The [CRFA] System instrumentation for each Function in Table 3.3.7.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.7.1-1.

ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Enter the Condition Immediately channels inoperable. referenced in Table 3.3.7.1-1 for the channel.

B. [ As required by B.1 Declare associated [CRFA] 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Required Action A.1 and subsystem inoperable. of loss of [CRFA]

referenced in initiation capability in Table 3.3.7.1-1. both trip systems AND B.2 Place channel in trip. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ]

C. [ As required by C.1 Declare associated [CRFA] 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Required Action A.1 and subsystem inoperable. of loss of [CRFA]

referenced in initiation capability in Table 3.3.7.1-1. both trip systems AND C.2 Place channel in trip. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ]

General Electric BWR/6 STS 3.3.7.1-1 Rev. 5.0

[CRFA] System Instrumentation 3.3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required D.1 Declare associated [CRFA] 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery Action A.1 and subsystem inoperable. of loss of [CRFA]

referenced in initiation capability in Table 3.3.7.1-1. both trip systems AND D.2 Place channel in trip. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> E. Required Action and E.1 ---------------NOTE--------------

associated Completion Place in toxic gas Time of Condition B, C, protection mode if or D not met. automatic transfer to toxic gas protection mode is inoperable.

Place the associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />

[CRFA] subsystem in the

[isolation] mode of operation.

OR E.2 Declare associated [CRFA] 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> subsystem inoperable.

General Electric BWR/6 STS 3.3.7.1-2 Rev. 5.0

[CRFA] System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains [CRFA] initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. [ [92] days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.7.1.3 [ Calibrate the trip units. [ [92] days OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.3.7.1-3 Rev. 5.0

[CRFA] System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.7.1-4 Rev. 5.0

[CRFA] System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)

[Control Room Fresh Air] System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water 1, 2, 3 [2] B SR 3.3.7.1.1 [-43.8] inches Level - Low Low, Level 2 SR 3.3.7.1.2

[SR 3.3.7.1.3]

SR 3.3.7.1.4 SR 3.3.7.1.5

2. Drywell Pressure - High 1, 2, 3 [2] C SR 3.3.7.1.1 [1.43] psig SR 3.3.7.1.2

[SR 3.3.7.1.3]

SR 3.3.7.1.4 SR 3.3.7.1.5

3. Control Room Ventilation 1, 2, 3, (a) [2] D SR 3.3.7.1.1 [5] mR/hr Radiation Monitors SR 3.3.7.1.2 SR 3.3.7.1.4 SR 3.3.7.1.5 (a) During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment]

General Electric BWR/6 STS 3.3.7.1-5 Rev. 5.0

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

---

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable.

[OR In accordance with the Risk Informed Completion Time Program]

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

Time not met.

General Electric BWR/6 STS 3.3.8.1-1 Rev. 5.0

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 [ Perform CHANNEL CHECK. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.8.1-2 Rev. 5.0

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.8.1-3 Rev. 5.0

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation REQUIRED CHANNELS PER SURVEILLANCE ALLOWABLE FUNCTION DIVISION REQUIREMENTS VALUE

1. Divisions 1 and 2 - 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1] [2621] V and [2912] V SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4

b. Loss of Voltage - Time Delay [4] [SR 3.3.8.1.2] [0.4] seconds and SR 3.3.8.1.3 [1.0] seconds SR 3.3.8.1.4

c. Degraded Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1] [3744] V and SR 3.3.8.1.2 [3837.6] V SR 3.3.8.1.3 SR 3.3.8.1.4

d. Degraded Voltage - Time Delay [4] [SR 3.3.8.1.2] [8.5] seconds and SR 3.3.8.1.3 [9.5] seconds SR 3.3.8.1.4

2. Division 3 - 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1] 2984 V and 3106 V SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4

b. Loss of Voltage - Time Delay [4] [SR 3.3.8.1.2] [2.0] seconds and SR 3.3.8.1.3 [2.5] seconds SR 3.3.8.1.4

c. Degraded Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1] 3558.5 V and SR 3.3.8.1.2 3763.5 V SR 3.3.8.1.3 SR 3.3.8.1.4

d. Degraded Voltage - Time Delay, No [4] [SR 3.3.8.1.2] [4.5] minutes and LOCA SR 3.3.8.1.3 [5.5] minutes SR 3.3.8.1.4

e. Degraded Voltage - Time Delay, [4] [SR 3.3.8.1.2] [3.6] seconds and LOCA SR 3.3.8.1.3 4.4 seconds SR 3.3.8.1.4 General Electric BWR/6 STS 3.3.8.1-4 Rev. 5.0

RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply.

APPLICABILITY: MODES 1, 2, and 3, MODES 4 and 5 [with any control rod withdrawn from a core cell containing one or more fuel assemblies].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> power supplies with one inservice power supply(s) electric power from service.

monitoring assembly inoperable.

B. One or both inservice B.1 Remove associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> power supplies with both inservice power supply(s) electric power from service.

monitoring assemblies inoperable.

C. Required Action and C.1 --------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when entering not met in MODE 1, 2, MODE 3.

or 3. -------------------------------------

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> General Electric BWR/6 STS 3.3.8.2-1 Rev. 5.0

RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to fully insert Immediately associated Completion all insertable control rods in Time of Condition A or B core cells containing one or not met in MODE 4 or 5 more fuel assemblies.

[with any control rod withdrawn from a core AND cell containing one or more fuel assemblies]. D.2.1 Initiate action to restore one Immediately electric power monitoring assembly to OPERABLE status for inservice power supply(s) supplying required instrumentation.

OR D.2.2 [ Initiate action to isolate the Immediately ]

Residual Heat Removal Shutdown Cooling System.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 -------------------------------NOTE------------------------------

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

Perform CHANNEL FUNCTIONAL TEST. [ 184 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.8.2-2 Rev. 5.0

RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable [ [18] months Values shall be:

OR

a. Overvoltage In accordance Bus A [132.9] V with the Bus B [133.0] V Surveillance Frequency

b. Undervoltage Control Program ]

Bus A [115.0] V Bus B [115.9] V

c. Underfrequency (with time delay set to [zero])

Bus A [57] Hz Bus B [57] Hz SR 3.3.8.2.3 Perform a system functional test. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.3.8.2-3 Rev. 5.0

Recirculation Loops Operating 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LCO 3.4.1 Two recirculation loops with matched flows shall be in operation, OR

[ One recirculation loop may be in operation provided the following limits are applied when the associated LCO is applicable:

a. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," single loop operation limits [specified in the COLR],

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," single loop operation limits [specified in the COLR], and

c. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation,"

Function 2.b (Average Power Range Monitors Flow Biased Simulated Thermal Power - High), Allowable Value of Table 3.3.1.1-1 is reset for single loop operation. ]

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

REVIEWERS NOTE--------------------------------------------------

Refer to the following topical reports for the resolution for the Stability Technical Specifications:

• Enhanced Option 1A NEDO-32339 Supplement 4

• Option 1D NEDO-1760 Supplement 1 and NEDO-32465

• GE-Option III NEDC-32410 and NEDC-32410 Supplement 1

• ABB Option III CENPD-400 Rev. 1.

CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the requirements of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> LCO not met. the LCO.

General Electric BWR/6 STS 3.4.1-1 Rev. 5.0

Recirculation Loops Operating 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met.

OR No recirculation loops in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 -------------------------------NOTE------------------------------

Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after both recirculation loops are in operation.

Verify recirculation loop jet pump flow mismatch with [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> both recirculation loops in operation is:

OR

a. [10]% of rated core flow when operating at

< [70]% of rated core flow and In accordance with the

b. [5]% of rated core flow when operating at Surveillance

[70]% of rated core flow. Frequency Control Program ]

General Electric BWR/6 STS 3.4.1-2 Rev. 5.0

FCVs 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs)

LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

Separate Condition entry is allowed for each FCV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Lock up the FCV. 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> FCVs inoperable.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify each FCV fails "as is" on loss of hydraulic [ [18] months pressure at the hydraulic unit.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.2-1 Rev. 5.0

FCVs 3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.2.2 Verify average rate of each FCV movement is: [ [18] months

a. [11]% of stroke per second for opening and OR

b. [11]% of stroke per second for closing. In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.2-2 Rev. 5.0

Jet Pumps 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Jet Pumps LCO 3.4.3 All jet pumps shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more jet pumps A.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> inoperable.

General Electric BWR/6 STS 3.4.3-1 Rev. 5.0

Jet Pumps 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ------------------------------NOTES-----------------------------

1. Not required to be performed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after associated recirculation loop is in operation.

2. Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after > 25% RTP.

Verify at least two of the following criteria (a, b, [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and c) are satisfied for each operating recirculation loop: OR

a. Recirculation loop drive flow versus flow control In accordance valve position differs by 10% from established with the patterns. Surveillance Frequency

b. Recirculation loop drive flow versus total core Control Program ]

flow differs by 10% from established patterns.

c. Each jet pump diffuser to lower plenum differential pressure differs by 20% from established patterns, or each jet pump flow differs by 10% from established patterns.

---

REVIEWER'S NOTE-------------------------------------------------

An acceptable option to these criteria for jet pump OPERABILITY can be found in the BWR/4 STS, NUREG-1433.

General Electric BWR/6 STS 3.4.3-2 Rev. 5.0

S/RVs 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 Safety/Relief Valves (S/RVs)

LCO 3.4.4 The safety function of [seven] S/RVs shall be OPERABLE, AND The relief function of [seven] additional S/RVs shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [ One [required] S/RV A.1 Restore [required] S/RV to 14 days inoperable. OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program] ]

B. [ Required Action and B.1 --------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. ] MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> C. [Two] or more [required] C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> S/RVs inoperable.

AND C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.4.4-1 Rev. 5.0

S/RVs 3.4.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 -------------------------------NOTE------------------------------

[2] [required] S/RVs may be changed to a lower setpoint group.

Verify the safety function lift setpoints of the [ In accordance

[required] S/RVs are as follows: with the INSERVICE Number of Setpoint TESTING S/RVs (psig) PROGRAM

[8] [1165 +/- 34.9] OR

[6] [1180 +/- 35.4]

[6] [1190 +/- 35.7] ((18] months]

Following testing, lift settings shall be within +/- 1%. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.4.4.2 -------------------------------NOTE------------------------------

Valve actuation may be excluded.

Verify each [required] relief function S/RV actuates [ [18] months on an actual or simulated automatic initiation signal.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.4-2 Rev. 5.0

S/RVs 3.4.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.4.3 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each [required] S/RV opens when manually [ [18] months on a actuated. STAGGERED TEST BASIS for each valve solenoid OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.4-3 Rev. 5.0

RCS Operational LEAKAGE 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Operational LEAKAGE LCO 3.4.5 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE,

b. 5 gpm unidentified LEAKAGE, [and]

c. [30] gpm total LEAKAGE averaged over the previous 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period, and

[ [d. 2 gpm increase in unidentified LEAKAGE within the previous

[4] hour period in MODE 1. ]

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressure boundary A.1 Isolate affected component, 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> LEAKAGE exists. pipe, or vessel from the RCS by use of a closed manual valve, closed and de-activated automatic valve, blind flange, or check valve.

B. Unidentified LEAKAGE B.1 Reduce LEAKAGE to within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> not within limit. limits.

OR Total LEAKAGE not within limit.

C. Unidentified LEAKAGE C.1 Reduced LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> increase not within limit. within limit.

OR General Electric BWR/6 STS 3.4.5-1 Rev. 5.0

RCS Operational LEAKAGE 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.2 Verify source of unidentified 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> LEAKAGE increase is not service sensitive type 304 or type 316 austenitic stainless steel.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified and total LEAKAGE and [ 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> unidentified LEAKAGE increase are within limits.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.5-2 Rev. 5.0

RCS PIV Leakage 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.6 The leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1 and 2, MODE 3, except valves in the residual heat removal (RHR) shutdown cooling flow path when in, or during the transition to or from, the shutdown cooling mode of operation.

ACTIONS

---

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

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by PIVs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths --------------------NOTE-------------------

with leakage from one or Each valve used to satisfy Required more RCS PIVs not Action A.1 and Required Action A.2 within limit. shall have been verified to meet SR 3.4.6.1 and be in the reactor coolant pressure boundary [or the high pressure portion of the system].

A.1 Isolate the high pressure 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND General Electric BWR/6 STS 3.4.6-1 Rev. 5.0

RCS PIV Leakage 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 Isolate the high pressure 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 -------------------------------NOTE------------------------------

Not required to be performed in MODE 3.

Verify equivalent leakage of each RCS PIV is [ In accordance 0.5 gpm per nominal inch of valve size up to a with INSERVICE maximum of 5 gpm, at an RCS pressure TESTING

[1040] psig and [1060] psig. PROGRAM OR

((18] months OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.6-2 Rev. 5.0

RCS Leakage Detection Instrumentation 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Leakage Detection Instrumentation LCO 3.4.7 The following RCS leakage detection instrumentation shall be OPERABLE:

a. Drywell floor drain sump monitoring system, [and]

b. One channel of either drywell atmospheric particulate or atmospheric gaseous monitoring system, [ and

[c. Drywell air cooler condensate flow rate monitoring system. ]

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell floor drain sump A.1 Restore drywell floor drain 30 days monitoring system sump monitoring system to inoperable. OPERABLE status.

B. Required drywell B.1 Analyze grab samples of Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> atmospheric monitoring drywell atmosphere.

system inoperable.

AND B.2 [ Restore required drywell 30 days ]

atmospheric monitoring system to OPERABLE status.

General Electric BWR/6 STS 3.4.7-1 Rev. 5.0

RCS Leakage Detection Instrumentation 3.4.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. [ Drywell air cooler C.1 --------------NOTE--------------

condensate flow rate Not applicable when the monitoring system required drywell inoperable. atmospheric monitoring system is inoperable.

Perform SR 3.4.7.1. Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> ]

---

NOTE -------------- D.1 Analyze grab samples of Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Only applicable when the the drywell atmosphere.

drywell atmospheric gaseous monitoring system AND is the only OPERABLE monitor. D.2 Monitor RCS LEAKAGE by Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

---

administrative means.

D. Drywell floor drain sump AND monitoring system inoperable. D.3.1 Restore drywell floor drain 7 days sump monitoring system to AND OPERABLE status.

[ Drywell air cooler OR condensate flow rate monitoring system [ D.3.2 Restore drywell air cooler 7 days ]

inoperable. ] condensate flow rate monitoring system to OPERABLE status.

E. [ Required drywell E.1 Restore required drywell 30 days atmospheric monitoring atmospheric monitoring system inoperable. system to OPERABLE status.

AND OR Drywell air cooler condensate flow rate E.2 Restore drywell air cooler 30 days ]

monitoring system condensate flow rate inoperable. monitoring system to OPERABLE status.

General Electric BWR/6 STS 3.4.7-2 Rev. 5.0

RCS Leakage Detection Instrumentation 3.4.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, B, AND

[C, D, or E] not met.

F.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> G. All required leakage G.1 Enter LCO 3.0.3. Immediately detection systems inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> atmospheric monitoring system.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.7-3 Rev. 5.0

RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of required [ 31 days leakage detection instrumentation.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.4.7.3 Perform CHANNEL CALIBRATION of required [ [18] months leakage detection instrumentation.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.7-4 Rev. 5.0

RCS Specific Activity 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Specific Activity LCO 3.4.8 The specific activity of the reactor coolant shall be limited to DOSE EQUIVALENT I-131 specific activity [0.2] Ci/gm.

APPLICABILITY: MODE 1, MODES 2 and 3 with any main steam line not isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor coolant specific --------------------NOTE-------------------

activity > [0.2] Ci/gm LCO 3.0.4.c is applicable.

and 4.0 Ci/gm DOSE ------------------------------------------------

EQUIVALENT I-131.

A.1 Determine DOSE Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> EQUIVALENT I-131.

AND A.2 Restore DOSE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> EQUIVALENT I-131 to within limits.

B. Required Action and B.1 Determine DOSE Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion EQUIVALENT I-131.

Time of Condition A not met. AND OR B.2.1 Isolate all main steam lines. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Reactor coolant OR specific activity

> [4.0] Ci/gm DOSE B.2.2.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> EQUIVALENT I-131.

AND General Electric BWR/6 STS 3.4.8-1 Rev. 5.0

RCS Specific Activity 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2.2.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 -------------------------------NOTE------------------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT I-131 [ 7 days specific activity is [0.2] Ci/gm.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.8-2 Rev. 5.0

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown LCO 3.4.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

---

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

1. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for performance of Surveillances.

APPLICABILITY: MODE 3 with reactor steam dome pressure < [the RHR cut in permissive pressure].

ACTIONS

---

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

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One [required] RHR A.1 Verify an alternate method 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> shutdown cooling of decay heat removal is subsystem inoperable. available. AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter B. Required Action and B.1 Initiate action to restore Immediately associated Completion RHR shutdown cooling Time of Condition A not subsystem to OPERABLE met. status.

General Electric BWR/6 STS 3.4.9-1 Rev. 5.0

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two [required] RHR C.1 Verify an alternate method 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> shutdown cooling of decay heat removal is subsystems inoperable. available for each AND inoperable RHR shutdown cooling subsystem. Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter D. Required Action and ---------------------NOTE-----------------

associated Completion LCO 3.0.3 and all other LCO Time of Condition C not Required Actions requiring a MODE met. change to MODE 4 may be suspended until one RHR shutdown cooling subsystem is restored to OPERABLE status.

D.1 Initiate action to restore one Immediately RHR shutdown cooling subsystem to OPERABLE status.

E. No RHR shutdown E.1 Initiate action to restore one Immediately cooling subsystem in RHR shutdown cooling operation. subsystem or one recirculation pump to AND operation.

No recirculation pump in AND operation.

E.2 Verify reactor coolant 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery circulation by an alternate of no reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND E.3 Monitor reactor coolant Once per hour temperature and pressure.

General Electric BWR/6 STS 3.4.9-2 Rev. 5.0

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 -------------------------------NOTE------------------------------

Not required to be met until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reactor steam dome pressure is < [the RHR cut in permissive pressure].

Verify one RHR shutdown cooling subsystem or [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> recirculation pump is operating.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.4.9.2 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam dome pressure is < [the RHR cut in permissive pressure].

Verify RHR shutdown cooling subsystem locations [ 31 days susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.9-3 Rev. 5.0

RHR Shutdown Cooling System - Cold Shutdown 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown LCO 3.4.10 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

---

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

1. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for the performance of Surveillances.

APPLICABILITY: MODE 4.

ACTIONS

---

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

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Verify an alternate method 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> shutdown cooling of decay heat removal is subsystems inoperable. available for each AND inoperable RHR shutdown cooling subsystem. Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter B. Required Action and B.1 Initiate action to restore Immediately associated Completion RHR shutdown cooling Time of Condition A not subsystem(s) to met. OPERABLE status.

General Electric BWR/6 STS 3.4.10-1 Rev. 5.0

RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. No RHR shutdown C.1 Verify reactor coolant 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery cooling subsystem in circulating by an alternate of no reactor coolant operation. method. circulation AND AND No recirculation pump in Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> operation. thereafter AND C.2 Monitor reactor coolant Once per hour temperature and pressure.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> recirculation pump is operating.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.4.10.2 Verify RHR shutdown cooling subsystem locations [ 31 days susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.10-2 Rev. 5.0

RCS P/T Limits 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 RCS Pressure and Temperature (P/T) Limits LCO 3.4.11 RCS pressure, RCS temperature, RCS heatup and cooldown rates, and the recirculation pump starting temperature requirements shall be maintained within the limits specified in the PTLR.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE------------ A.1 Restore parameter(s) to 30 minutes Required Action A.2 within limits.

shall be completed if this Condition is entered. AND A.2 Determine RCS is 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Requirements of the acceptable for continued LCO not met in operation.

MODES 1, 2, and 3.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not AND met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> C. ------------NOTE------------ C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed if this limits.

Condition is entered.

---

AND Requirements of the C.2 Determine RCS is Prior to entering LCO not met in other acceptable for operation. MODE 2 or 3 than MODES 1, 2, and 3.

General Electric BWR/6 STS 3.4.11-1 Rev. 5.0

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 -------------------------------NOTE------------------------------

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

Verify RCS pressure, RCS temperature, and RCS [ 30 minutes heatup and cooldown rates are within the limits specified in the PTLR. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.4.11.2 Verify RCS pressure and RCS temperature are Once within within the criticality limits specified in the PTLR. 15 minutes prior to control rod withdrawal for the purpose of achieving criticality SR 3.4.11.3 -------------------------------NOTE------------------------------

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup [with reactor steam dome pressure 25 psig].

Verify the difference between the bottom head Once within coolant temperature and the reactor pressure vessel 15 minutes prior (RPV) coolant temperature is within the limits to each startup of specified in the PTLR. a recirculation pump General Electric BWR/6 STS 3.4.11-2 Rev. 5.0

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.11.4 -------------------------------NOTE------------------------------

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup.

Verify the difference between the reactor coolant Once within temperature in the recirculation loop to be started 15 minutes prior and the RPV coolant temperature is within the limits to each startup of specified in the PTLR. a recirculation pump SR 3.4.11.5 -------------------------------NOTE------------------------------

[ Only required to be met during a THERMAL POWER increase or recirculation flow increase in MODES 1 and 2 with one idle recirculation loop when [THERMAL POWER is 30% RTP or when operating loop flow is 50% rated loop flow].

Verify the difference between the bottom head Once within coolant temperature and the RPV coolant 15 minutes prior temperature is [ 145F]. to a THERMAL POWER increase or recirculation flow increase ]

SR 3.4.11.6 -------------------------------NOTE------------------------------

[ Only required to be met during a THERMAL POWER increase or recirculation flow increase in MODES 1 and 2 with one non-isolated idle recirculation loop when [THERMAL POWER is 30% RTP or when operating loop flow is 50%

rated loop flow].

Verify the difference between the reactor coolant Once within temperature in the idle recirculation loop and the 15 minutes prior RPV coolant temperature is [ 50F]. to a THERMAL POWER increase or recirculation flow increase ]

General Electric BWR/6 STS 3.4.11-3 Rev. 5.0

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.11.7 -------------------------------NOTE------------------------------

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify reactor vessel flange and head flange [ 30 minutes temperatures are within the limits specified in the PTLR. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.4.11.8 -------------------------------NOTE------------------------------

Not required to be performed until 30 minutes after RCS temperature 80F in MODE 4.

Verify reactor vessel flange and head flange [ 30 minutes temperatures are within the limits specified in the PTLR. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.11-4 Rev. 5.0

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.11.9 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after RCS temperature 100F in MODE 4.

Verify reactor vessel flange and head flange [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> temperatures are within the limits specified in the PTLR. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.11-5 Rev. 5.0

Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be [1045] psig.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam 15 minutes pressure not within limit. dome pressure to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is [1045] psig. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.4.12-1 Rev. 5.0

ECCS - Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS - Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of [eight] safety/relief valves shall be OPERABLE.

[ --------------------------------------------NOTE--------------------------------------------

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than [the residual heat removal cut in permissive pressure] in MODE 3, if capable of being manually realigned and not otherwise inoperable.

---

]

APPLICABILITY: MODE 1, MODES 2 and 3, except ADS valves are not required to be OPERABLE with reactor steam dome pressure [150] psig.

ACTIONS

---

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

LCO 3.0.4.b is not applicable to High Pressure Core Spray (HPCS).

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray ECCS injection/spray subsystem inoperable. subsystem to OPERABLE [OR status.

In accordance with the Risk Informed Completion Time Program]

B. HPCS System B.1 Verify by administrative Immediately inoperable. means RCIC System is OPERABLE when RCIC is required to be OPERABLE.

AND General Electric BWR/6 STS 3.5.1-1 Rev. 5.0

ECCS - Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2 Restore HPCS System to 14 days OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

C. Two ECCS injection C.1 Restore one ECCS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> subsystems inoperable. injection/spray subsystem to OPERABLE status. [OR OR In accordance with One ECCS injection and the Risk Informed one ECCS spray Completion Time subsystem inoperable. Program]

D. Required Action and D.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when entering or C not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. One ADS valve E.1 Restore ADS valve to 14 days inoperable. OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.5.1-2 Rev. 5.0

ECCS - Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. One ADS valve F.1 Restore ADS valve to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. OPERABLE status.

[OR AND In accordance with One low pressure ECCS the Risk Informed injection/spray Completion Time subsystem inoperable. Program]

OR F.2 Restore low pressure 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ECCS injection/spray subsystem to OPERABLE [OR status.

In accordance with the Risk Informed Completion Time Program]

G. Two or more ADS valves G.1 ---------------NOTE--------------

inoperable. LCO 3.0.4.a is not applicable when entering OR MODE 3.

Required Action and associated Completion Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Time of Condition E or F not met.

General Electric BWR/6 STS 3.5.1-3 Rev. 5.0

ECCS - Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. HPCS and low pressure H.1 Enter LCO 3.0.3. Immediately core spray (LPCS) inoperable.

OR Three or more ECCS injection/spray subsystems inoperable.

OR HPCS System and one or more ADS valves inoperable.

OR Two or more ECCS injection/spray subsystems and one or more ADS valves inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, [ 31 days locations susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.1-4 Rev. 5.0

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.2 ---------------------------------NOTE----------------------------

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

Verify each ECCS injection/spray subsystem [ 31 days manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise OR secured in position, is in the correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.5.1.3 Verify ADS [air receiver] pressure is [150] psig. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.5.1.4 Verify each ECCS pump develops the specified flow [ In accordance rate [against a system head corresponding to the with the specified reactor pressure]. INSERVICE TESTING

[System Head PROGRAM Corresponding to a Reactor OR System Flow Rate Pressure of]

[92 days]

LPCS [7115] gpm [290] psig LPCI [7450] gpm [125] psig OR HPCS [7115] gpm [445] psig In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.1-5 Rev. 5.0

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.5 -------------------------------NOTE------------------------------

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem [ [18] months actuates on an actual or simulated automatic initiation signal, except for valves that are locked, OR sealed, or otherwise secured in the actuated position. In accordance with the Surveillance Frequency Control Program ]

SR 3.5.1.6 -------------------------------NOTE------------------------------

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated [ [18] months automatic initiation signal.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.1-6 Rev. 5.0

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.7 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve opens when manually [ [18] months on a actuated. STAGGERED TEST BASIS for each valve solenoid OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.1-7 Rev. 5.0

RPV Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

AND One ECCS injection/spray subsystem shall be OPERABLE.

APPLICABILITY: MODES 4 and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> injection/spray injection/spray subsystem subsystem inoperable. to OPERABLE status.

B. Required Action and B.1 Initiate action to establish a Immediately associated Completion method of water injection Time of Condition A not capable of operating met. without offsite electrical power.

C. DRAIN TIME < 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> C.1 Verify [secondary 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. containment] boundary is capable of being established in less than the DRAIN TIME.

AND General Electric BWR/6 STS 3.5.2-1 Rev. 5.0

RPV Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.2 Verify each [secondary 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> containment] penetration flow path is capable of being isolated in less than the DRAIN TIME.

AND C.3 [ Verify one standby gas 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> ]

treatment (SGT) subsystem is capable of being placed in operation in less than the DRAIN TIME.

D. DRAIN TIME < 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. D.1 ----------- NOTE ---------------

Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power.

Initiate action to establish Immediately an additional method of water injection with water sources capable of maintaining RPV water level > TAF for 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

AND D.2 Initiate action to establish Immediately

[secondary containment]

boundary.

AND General Electric BWR/6 STS 3.5.2-2 Rev. 5.0

RPV Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.3 Initiate action to isolate Immediately each [secondary containment] penetration flow path or verify it can be

[automatically or] manually isolated from the control room.

AND D.4 [ Initiate action to verify one Immediately ]

SGT subsystem is capable of being placed in operation.

E. Required Action and E.1 Initiate action to restore Immediately associated Completion DRAIN TIME to 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

Time of Condition C or D not met.

OR DRAIN TIME < 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.2-3 Rev. 5.0

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for a required low pressure ECCS [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> injection/spray subsystem, the suppression pool water level is [12.67 ft]. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.5.2.3 Verify, for a required High Pressure Core Spray [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (HPCS) System, the:

OR

a. Suppression pool water level is [12.67 ft] or In accordance

b. Condensate storage tank water level is [18 ft]. with the Surveillance Frequency Control Program ]

SR 3.5.2.4 Verify, for the required ECCS injection/spray [ 31 days subsystem, locations susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.2-4 Rev. 5.0

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 ------------------------------NOTES-----------------------------

1. Operation may be through the test return line.

2. Credit may be taken for normal system operation to satisfy this SR.

Operate the required ECCS injection/spray [ 92 days subsystem for 10 minutes.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.5.2.6 Verify each valve credited for automatically isolating [ [18] months a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.5.2.7 -------------------------------NOTE------------------------------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray subsystem [ [18] months can be manually operated.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.2-5 Rev. 5.0

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > [150] psig.

ACTIONS

---

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

LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System A.1 Verify by administrative Immediately inoperable. means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System to 14 days OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> dome pressure to

[150] psig.

General Electric BWR/6 STS 3.5.3-1 Rev. 5.0

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas [ 31 days accumulation are sufficiently filled with water.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.5.3.2 -------------------------------NOTE------------------------------

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

Verify each RCIC System manual, power operated, [ 31 days and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is OR in the correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.5.3.3 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify, with [RCIC steam supply pressure] [ 92 days

[1045] psig and [945] psig, the RCIC pump can develop a flow rate [800] gpm [against a system OR head corresponding to reactor pressure].

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.3-2 Rev. 5.0

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.4 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify, with [RCIC steam supply pressure] [ [18] months

[165] psig, the RCIC pump can develop a flow rate

[800] gpm [against a system head corresponding OR to reactor pressure].

In accordance with the Surveillance Frequency Control Program ]

SR 3.5.3.5 -------------------------------NOTE------------------------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or [ [18] months simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured OR in the actuated position.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.5.3-3 Rev. 5.0

Primary Containment 3.6.1.1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment LCO 3.6.1.1 Primary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. containment to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and leakage In accordance rate testing except for primary containment air lock with the Primary testing, in accordance with the Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.1.2 [ Verify primary containment structural integrity in In accordance accordance with the Primary Containment Tendon with the Primary Surveillance Program. Containment Tendon Surveillance Program ]

General Electric BWR/6 STS 3.6.1.1-1 Rev. 5.0

Primary Containment Air Locks 3.6.1.2 3.6 CONTAINMENT SYSTEMS 3.6.1.2 Primary Containment Air Locks LCO 3.6.1.2 [Two] primary containment air locks shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

1. Entry and exit is permissible to perform repairs of the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment,"

when air lock leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more primary -------------------NOTES------------------

containment air locks 1. Required Actions A.1, A.2, with one primary and A.3 are not applicable if both containment air lock doors in the same air lock are door inoperable. inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls [if both air locks are inoperable].

General Electric BWR/6 STS 3.6.1.2-1 Rev. 5.0

Primary Containment Air Locks 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.1 Verify the OPERABLE door 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is closed in the affected air lock.

AND A.2 Lock the OPERABLE door 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 door Once per 31 days is locked closed in the affected air lock.

General Electric BWR/6 STS 3.6.1.2-2 Rev. 5.0

Primary Containment Air Locks 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more primary -------------------NOTES------------------

containment air locks 1. Required Actions B.1, B.2, with primary and B.3 are not applicable if both containment air lock doors in the same air lock are interlock mechanism inoperable and Condition C is inoperable. entered.

2. Entry into and exit from containment is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE door 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is closed in the affected air lock.

AND B.2 Lock an OPERABLE door 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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.

General Electric BWR/6 STS 3.6.1.2-3 Rev. 5.0

Primary Containment Air Locks 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more primary C.1 Initiate action to evaluate Immediately containment air locks primary containment overall inoperable for reasons leakage rate per other than Condition A LCO 3.6.1.1, using current or B. air lock test results.

AND C.2 Verify a door is closed in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the affected air lock.

AND C.3 Restore air lock to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.1.2-4 Rev. 5.0

Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 ------------------------------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 3.6.1.1.1.

Perform required primary containment air lock In accordance leakage rate testing in accordance with the Primary with the Primary Containment Leakage Rate Testing Program. Containment Leakage Rate Testing Program SR 3.6.1.2.2 [ Verify primary containment air lock seal air flask [ 7 days pressure is [90] psig.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.6.1.2.3 Verify only one door in the primary containment air [ 24 months lock can be opened at a time.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.2-5 Rev. 5.0

Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.2.4 [ Verify, from an initial pressure of [90] psig, the [ [18] months primary containment air lock seal pneumatic system pressure does not decay at a rate equivalent to OR

> [2] psig for a period of [48] hours.

In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.1.2-6 Rev. 5.0

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

LCO 3.6.1.3 Each PCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, When associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation."

ACTIONS

---

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

1. Penetration flow paths [except for [ ] inch purge valve penetration flow paths] 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 PCIVs.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment,"

when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, and 3.

General Electric BWR/6 STS 3.6.1.3-1 Rev. 5.0

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE------------ A.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> [for feedwater Only applicable to penetration flow path by isolation valves penetration flow paths use of at least one closed (FWIVs), residual with two [or more] and de-activated automatic heat removal (RHR)

PCIVs. valve, closed manual valve, shutdown cooling

---

blind flange, or check valve suction lines PCIVs, with flow through the valve and Low Pressure One or more penetration secured. Core Spray (LPCS) flow paths with one System PCIVs]

PCIV inoperable [for reasons other than [OR Condition[s] D [and E)).

In accordance with the Risk Informed Completion Time Program]

AND 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for main steam isolation valves (MSIVs)

[OR In accordance with the Risk Informed Completion Time Program]

[ AND 7 days except for FWIVs, RHR shutdown cooling suction line PCIVs, LPCS System PCIVs, and MSIVs ]

[OR In accordance with the Risk Informed AND Completion Time Program]

General Electric BWR/6 STS 3.6.1.3-2 Rev. 5.0

PCIVs 3.6.1.3 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 use of administrative means.

Verify the affected Once per 31 days penetration flow path is [following isolation]

isolated. for isolation devices outside primary containment, drywell, and steam tunnel AND Prior to entering MODE 2 or 3 from MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment, drywell, or steam tunnel General Electric BWR/6 STS 3.6.1.3-3 Rev. 5.0

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. ------------NOTE------------ B.1 Isolate the affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Only applicable to penetration flow path by penetration flow paths use of at least one closed with two [or more] and de-activated automatic PCIVs. valve, closed manual valve,

---

or blind flange.

One or more penetration flow paths with two [or more] PCIVs inoperable

[for reasons other than Condition[s] D [and E)).

C. ------------NOTE------------ C.1 Isolate the affected [4] hours except for Only applicable to penetration flow path by penetrations with a penetration flow paths use of at least one closed closed system with only one PCIV. and de-activated automatic

---

valve, closed manual valve, AND or blind flange.

One or more penetration [7 days] for flow paths with one penetrations with a PCIV inoperable [for closed system reasons other than Condition[s] D [and E)). AND C.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 use of administrative means.

Verify the affected Once per 31 days penetration flow path is [following isolation]

isolated.

General Electric BWR/6 STS 3.6.1.3-4 Rev. 5.0

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. [ One or more D.1 Restore leakage rate to [4 hours for

[secondary containment within limit. hydrostatically tested bypass leakage rate,] line leakage [not on a

[MSIV leakage rate,] closed system]

[purge valve leakage rate,] [or] [hydrostatically AND tested line leakage rate]

not within limit. [4 hours for secondary containment bypass leakage]

AND

[8 hours for MSIV leakage]

AND

[24 hours for purge valve leakage]

AND

[72 hours for hydrostatically tested line leakage] [on a closed system] ]

E. [ One or more E.1 Isolate the affected 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> penetration flow paths penetration flow path by with one or more use of at least one [closed [OR containment purge and de-activated automatic valves not within purge valve, closed manual valve, In accordance with valve leakage limits. or blind flange]. the Risk Informed Completion Time Program]

AND General Electric BWR/6 STS 3.6.1.3-5 Rev. 5.0

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.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 use of administrative means.

Verify the affected Once per 31 days penetration flow path is [following isolation]

isolated. for isolation devices outside containment AND Prior to entering MODE 2 or 3 from MODE 4 if not performed within the previous 92 days for isolation devices inside containment AND E.3 Perform SR 3.6.1.3.6 for the resilient seal purge Once per [92] days valves closed to comply [following isolation] ]

with Required Action E.1.

F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, B, AND C, D, or E not met in MODE 1, 2, or 3. F.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.1.3-6 Rev. 5.0

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. [ Required Action and G.1 ---------------NOTE--------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A, B, -------------------------------------

C, D, or E not met for PCIV(s) required to be Suspend movement of Immediately ]

OPERABLE during [recently] irradiated fuel movement of [recently] assemblies in [primary and irradiated fuel secondary containment].

assemblies in the

[primary or secondary containment].

H. [ Required Action and H.1 Initiate action to restore Immediately ]

Associated Completion valve(s) to OPERABLE Time of Condition A, B, status.

C, D, or E not met for PCIV(s) required to be OPERABLE during MODE 4 or 5.

General Electric BWR/6 STS 3.6.1.3-7 Rev. 5.0

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 -------------------------------NOTE------------------------------

[ [Only required to be met in MODES 1, 2, and 3.]

Verify each [ ] inch primary containment purge [ 31 days valve is sealed closed except for one purge valve in a penetration flow path while in Condition E of this OR LCO.

In accordance with the Surveillance Frequency Control Program ] ]

SR 3.6.1.3.2 ------------------------------NOTES-----------------------------

[ 1. [Only required to be met in MODES 1, 2, and 3.]

2. Not required to be met when the [20] inch primary containment purge valves are open for pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open, provided the drywell [purge supply and exhaust] lines are isolated.

Verify each [20] inch primary containment purge [ 31 days valve is closed.

OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.1.3-8 Rev. 5.0

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.3 ------------------------------NOTES-----------------------------

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

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation manual [ 31 days valve and blind flange that is located outside primary containment, drywell, and steam tunnel and not OR locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.3.4 ------------------------------NOTES-----------------------------

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

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation manual Prior to entering valve and blind flange that is located inside primary MODE 2 or 3 from containment, drywell, or steam tunnel and not MODE 4, if not locked, sealed, or otherwise secured and is required performed within to be closed during accident conditions is closed. the previous 92 days General Electric BWR/6 STS 3.6.1.3-9 Rev. 5.0

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.5 Verify the isolation time of each power operated, [ In accordance automatic PCIV[, except MSIVs,] is within limits. with the INSERVICE TESTING PROGRAM OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.3.6 -------------------------------NOTE------------------------------

[ [Only required to be met in MODES 1, 2, and 3.]

Perform leakage rate testing for each primary [ 184 days containment purge valve with resilient seals.

OR In accordance with the Surveillance Frequency Control Program ]

AND Once within 92 days after opening the valve ]

General Electric BWR/6 STS 3.6.1.3-10 Rev. 5.0

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.7 Verify the isolation time of each MSIV is [ In accordance

[3] seconds and [5] seconds. with the INSERVICE TESTING PROGRAM OR

((18] months]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.3.8 Verify each automatic PCIV actuates to the isolation [ [18] months position on an actual or simulated isolation signal.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.3.9 -------------------------------NOTE------------------------------

[ [Only required to be met in MODES 1, 2, and 3.]

Verify the combined leakage rate for all secondary In accordance containment bypass leakage paths is [ ] La when with the Primary pressurized to [ ] psig. Containment Leakage Rate Testing Program ]

General Electric BWR/6 STS 3.6.1.3-11 Rev. 5.0

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.10 -------------------------------NOTE------------------------------ [In accordance

[Only required to be met in MODES 1, 2, and 3.] with the Primary

---

Containment Leakage Rate Verify leakage rate through all four main steam lines Testing Program]

is [100] scfh when tested at [11.5] psig.

SR 3.6.1.3.11 -------------------------------NOTE------------------------------

[Only required to be met in MODES 1, 2, and 3.]

Verify combined leakage rate through hydrostatically In accordance tested lines that penetrate the primary containment with the Primary is within limits. Containment Leakage Rate Testing Program SR 3.6.1.3.12 -------------------------------NOTE------------------------------

[ [Only required to be met in MODES 1, 2, and 3.]

Verify each [ ] inch primary containment purge [ [18] months valve is blocked to restrict the valve from opening

> [50]%. OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.1.3-12 Rev. 5.0

Primary Containment Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Primary Containment Pressure LCO 3.6.1.4 Primary containment [to secondary containment differential] pressure shall be [ -0.1 psid and 1.0 psid].

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment [to A.1 Restore primary 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> secondary containment containment [to secondary differential] pressure not containment differential]

within limits. pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify primary containment [to secondary [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> containment differential] pressure is within limits.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.4-1 Rev. 5.0

Primary Containment Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Primary Containment Air Temperature LCO 3.6.1.5 Primary containment average air temperature shall be [95]F.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> average air temperature containment average air not within limit. temperature to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify primary containment average air temperature [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> is within limit.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.5-1 Rev. 5.0

LLS Valves 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Low-Low Set (LLS) Valves LCO 3.6.1.6 The LLS function of [six] safety/relief valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One LLS valve A.1 Restore LLS valve to 14 days inoperable. OPERABLE status.

B. Required Action and B.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> C. Two or more LLS valves C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> inoperable.

AND C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.1.6-1 Rev. 5.0

LLS Valves 3.6.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each LLS valve opens when manually [ [18] months [on actuated. a STAGGERED TEST BASIS for each valve solenoid]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.6.2 -------------------------------NOTE------------------------------

Valve actuation may be excluded.

Verify the LLS System actuates on an actual or [ 18 months simulated automatic initiation signal.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.6-2 Rev. 5.0

RHR Containment Spray System 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Residual Heat Removal (RHR) Containment Spray System LCO 3.6.1.7 Two RHR containment spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR containment A.1 Restore RHR containment 7 days spray subsystem spray subsystem to inoperable. OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program]

B. Two RHR containment B.1 Restore one RHR 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> spray subsystems containment spray inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> General Electric BWR/6 STS 3.6.1.7-1 Rev. 5.0

RHR Containment Spray System 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 -------------------------------NOTES----------------------------

1. RHR containment spray subsystems may be considered OPERABLE during alignment and operation for decay heat removal when below

[the RHR cut in permissive pressure in MODE 3]

if capable of being manually realigned and not otherwise inoperable.

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

Verify each RHR containment spray subsystem [ 31 days manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise OR secured in position is in the correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.7.2 Verify RHR containment spray subsystem locations [ 31 days susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.7-2 Rev. 5.0

RHR Containment Spray System 3.6.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.7.3 Verify each RHR pump develops a flow rate of [ In accordance

[5650] gpm on recirculation flow through the with the associated heat exchanger to the suppression pool. INSERVICE TESTING PROGRAM OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.7.4 Verify each RHR containment spray subsystem [ [18] months automatic valve in the flow path actuates to its correct position on an actual or simulated automatic OR initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated In accordance position. with the Surveillance Frequency Control Program ]

SR 3.6.1.7.5 Verify each spray nozzle is unobstructed. [At first refueling]

AND

[ 10 years OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.7-3 Rev. 5.0

PVLCS 3.6.1.8 3.6 CONTAINMENT SYSTEMS 3.6.1.8 Penetration Valve Leakage Control System (PVLCS)

LCO 3.6.1.8 [Two] PVLCS subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One PVLCS subsystem A.1 Restore PVLCS 30 days inoperable. subsystems to OPERABLE status.

B. [Two] PVLCS B.1 Restore one PVLCS 7 days subsystems inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> General Electric BWR/6 STS 3.6.1.8-1 Rev. 5.0

PVLCS 3.6.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.8.1 Verify air pressure in each subsystem is [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[101] psig.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.8.2 Perform a system functional test of each PVLCS [ [18] months subsystem.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.8-2 Rev. 5.0

MSIV LCS 3.6.1.9 3.6 CONTAINMENT SYSTEMS 3.6.1.9 Main Steam Isolation Valve (MSIV) Leakage Control System (LCS)

LCO 3.6.1.9 Two MSIV LCS subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIV LCS A.1 Restore MSIV LCS 30 days subsystem inoperable. subsystem to OPERABLE status.

B. Two MSIV LCS B.1 Restore one MSIV LCS 7 days subsystems inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> General Electric BWR/6 STS 3.6.1.9-1 Rev. 5.0

MSIV LCS 3.6.1.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.9.1 Operate each MSIV LCS blower [15] minutes. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.9.2 Verify electrical continuity of each inboard MSIV [ 31 days LCS subsystem heater element circuitry.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.1.9.3 Perform a system functional test of each MSIV LCS [ [18] months subsystem.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.1.9-2 Rev. 5.0

Suppression Pool Average Temperature 3.6.2.1 3.6 CONTAINMENT SYSTEMS 3.6.2.1 Suppression Pool Average Temperature LCO 3.6.2.1 Suppression pool average temperature shall be:

a. [95]F [when any OPERABLE intermediate range monitor (IRM) channel is > [25/40] divisions of full scale on Range 7] [with THERMAL POWER > 1% RTP], and no testing that adds heat to the suppression pool is being performed,

b. [105]F [when any OPERABLE IRM channel is > [25/40] divisions of full scale on Range 7] [with THERMAL POWER > 1% RTP], and testing that adds heat to the suppression pool is being performed, and

c. [110]F [when all OPERABLE IRM channels are [25/40]

divisions of full scale on Range 7] [with THERMAL POWER 1% RTP].

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool A.1 Verify suppression pool Once per hour average temperature average temperature is

> [95]F but [110]F. [110]F.

AND AND

[Any OPERABLE IRM A.2 Restore suppression pool 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> channel > [25/40] average temperature to divisions of full scale on [95]F.

Range 7] [THERMAL POWER > 1% RTP].

AND Not performing testing that adds heat to the suppression pool.

General Electric BWR/6 STS 3.6.2.1-1 Rev. 5.0

Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Reduce THERMAL 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion POWER [until all Time of Condition A not OPERABLE IRM channels met. are [25/40] divisions of full scale on Range 7] [to 1% RTP].

C. Suppression pool C.1 Suspend all testing that Immediately average temperature adds heat to the

> [105]F. suppression pool.

AND

[Any OPERABLE IRM channel > [25/40]

divisions of full scale on Range 7] [THERMAL POWER > 1% RTP].

AND Performing testing that adds heat to the suppression pool.

D. Suppression pool D.1 Place the reactor mode Immediately average temperature switch in the shutdown

> [110]F but [120]F. position.

AND D.2 Verify suppression pool Once per 30 minutes average temperature is

[120]F.

AND D.3 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.2.1-2 Rev. 5.0

Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Suppression pool E.1 Depressurize the reactor 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> average temperature vessel to < [200] psig.

> [120]F.

AND E.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average temperature is [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> within the applicable limits.

OR In accordance with the Surveillance Frequency Control Program ]

AND 5 minutes when performing testing that adds heat to the suppression pool General Electric BWR/6 STS 3.6.2.1-3 Rev. 5.0

Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be [18 ft 4.5 inches] and [18 ft 9.75 inches]

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression pool 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> level not within limits. water level to within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is within limits. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.2.2-1 Rev. 5.0

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 Two RHR suppression pool cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR suppression 7 days pool cooling subsystem pool cooling subsystem to inoperable. OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program]

B. Required Action and B.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.

Be MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> C. Two RHR suppression C.1 Restore one RHR 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> pool cooling subsystems suppression pool cooling inoperable. subsystem to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition C not AND met.

D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.2.3-1 Rev. 5.0

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling [ 31 days subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, or OR otherwise secured in position is in the correct position or can be aligned to the correct position. In accordance with the Surveillance Frequency Control Program ]

SR 3.6.2.3.2 Verify RHR suppression pool cooling subsystem [ 31 days locations susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.2.3.3 Verify each RHR pump develops a flow rate [ In accordance

[7450] gpm through the associated heat with the exchanger while operating in the suppression pool INSERVICE cooling mode. TESTING PROGRAM OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.2.3-2 Rev. 5.0

SPMU System 3.6.2.4 3.6 CONTAINMENT SYSTEMS 3.6.2.4 Suppression Pool Makeup (SPMU) System LCO 3.6.2.4 Two SPMU subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Upper containment pool A.1 Restore upper containment 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> water level not within pool water level to within limit. limit.

B. Upper containment pool B.1 Restore upper containment 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> water temperature not pool water temperature to within limit. within limit.

C. One SPMU subsystem C.1 Restore SPMU subsystem 7 days inoperable for reasons to OPERABLE status.

other than Condition A [OR or B.

In accordance with the Risk Informed Completion Time Program]

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.2.4-1 Rev. 5.0

SPMU System 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.1 Verify upper containment pool water level is [23 ft [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 3 inches] above the pool bottom.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.2.4.2 Verify upper containment pool water temperature is [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[125]F.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.2.4.3 Verify each SPMU subsystem manual, power [ 31 days operated, and automatic valve that is not locked, sealed, or otherwise secured in position is in the OR correct position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.2.4.4 [ Verify all upper containment pool gates are in the [ 31 days stored position or are otherwise removed from the upper containment pool. OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.2.4-2 Rev. 5.0

SPMU System 3.6.2.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.2.4.5 -------------------------------NOTE------------------------------

Actual makeup to the suppression pool may be excluded.

Verify each SPMU subsystem automatic valve [ [18] months actuates to the correct position on an actual or simulated automatic initiation signal. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.2.4-3 Rev. 5.0

Primary Containment and Drywell Hydrogen Ignitors 3.6.3.1 3.6 CONTAINMENT SYSTEMS 3.6.3.1 Primary Containment and Drywell Hydrogen Ignitors LCO 3.6.3.1 Two divisions of primary containment and drywell hydrogen ignitors shall be OPERABLE, each with > 90% of the associated ignitor assemblies OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One primary A.1 Restore primary 30 days containment and drywell containment and drywell hydrogen ignitor division hydrogen ignitor division to inoperable. OPERABLE status.

B. Two primary B.1 Verify by administrative 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> containment and drywell means that the hydrogen hydrogen ignitor control function is AND divisions inoperable. maintained.

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND B.2 Restore one primary 7 days containment and drywell hydrogen ignitor division to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

General Electric BWR/6 STS 3.6.3.1-1 Rev. 5.0

Primary Containment and Drywell Hydrogen Ignitors 3.6.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1.1 Energize each primary containment and drywell [ 184 days hydrogen ignitor division and perform current versus voltage measurements to verify required ignitors in OR service.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.3.1.2 -------------------------------NOTE------------------------------

Not required to be performed until 92 days after discovery of four or more ignitors in the division inoperable.

Energize each primary containment and drywell [ 92 days hydrogen ignitor division and perform current versus voltage measurements to verify required ignitors in OR service.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.3.1.3 Verify each required ignitor in inaccessible areas [ [18] months develops sufficient current draw for a [1700]F surface temperature. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.3.1-2 Rev. 5.0

Primary Containment and Drywell Hydrogen Ignitors 3.6.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1.4 Verify each required ignitor in accessible areas [ [18] months develops a surface temperature of [1700]F.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.3.1-3 Rev. 5.0

[Drywell Purge System]

3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 [Drywell Purge System]

LCO 3.6.3.2 Two [drywell purge] subsystems shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One [drywell purge] A.1 Restore [drywell purge] 30 days subsystem inoperable. subsystem to OPERABLE status.

B. Two [drywell purge] B.1 Verify by administrative 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> subsystems inoperable. means that the hydrogen control function is AND maintained.

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND B.2 Restore one [drywell purge] 7 days subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

General Electric BWR/6 STS 3.6.3.2-1 Rev. 5.0

[Drywell Purge System]

3.6.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Operate each [drywell purge] subsystem for [ 92 days

[15] minutes.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.3.2.2 [ Verify each [drywell purge] subsystem flow rate is [ [18] months

[500] scfm.

OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.3.2-2 Rev. 5.0

[Secondary Containment]

3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 [Secondary Containment]

LCO 3.6.4.1 The [secondary containment] shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3,

[ During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [Secondary containment] A.1 Restore [secondary 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> inoperable [in MODE 1, containment] to 2, or 3]. OPERABLE status.

B. Required Action and B.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time [of Condition A] not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> C. [ [Secondary C.1 ---------------NOTE--------------

containment] inoperable LCO 3.0.3 is not applicable.

during movement of -------------------------------------

[recently] irradiated fuel assemblies in the Suspend movement of Immediately

[primary or secondary [recently] irradiated fuel containment]. assemblies in the [primary and secondary containment].

General Electric BWR/6 STS 3.6.4.1-1 Rev. 5.0

[Secondary Containment]

3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 [ ----------------------------NOTE------------------------------

Not required to be met for 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> if analysis demonstrates one standby gas treatment (SGT) subsystem is capable of establishing the required

[secondary containment] vacuum.

Verify [secondary containment] vacuum is [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[0.25] inch of vacuum water gauge.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.6.4.1.2 Verify all [secondary containment] equipment [ 31 days hatches are closed and sealed.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.4.1.3 Verify one [secondary containment] access door in [ 31 days each access opening is closed, except when the access opening is being used for entry and exit. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.4.1-2 Rev. 5.0

[Secondary Containment]

3.6.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.4.1.4 [ Verify the [secondary containment] can be drawn [ [18] months on a down to [0.25] inch of vacuum water gauge in STAGGERED

[120] seconds using one SGT subsystem. TEST BASIS for each SGT subsystem OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.6.4.1.5 Verify the [secondary containment] can be [ [18] months on a maintained [0.266] inch of vacuum water gauge STAGGERED for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> using one SGT subsystem at a flow rate TEST BASIS for

[4000] cfm. each SGT subsystem OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.4.1-3 Rev. 5.0

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)

LCO 3.6.4.2 Each SCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

ACTIONS

---

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

1. Penetration flow paths 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 SCIVs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> flow paths with one penetration flow path by SCIV inoperable. use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange.

AND General Electric BWR/6 STS 3.6.4.2-1 Rev. 5.0

SCIVs 3.6.4.2 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 use of administrative means.

Verify the affected Once per 31 days penetration flow path is isolated.

B. ------------NOTE------------ B.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated automatic

---

valve, closed manual valve, or blind flange.

One or more penetration flow paths with two SCIVs inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A or B AND not met in MODE 1, 2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.4.2-2 Rev. 5.0

SCIVs 3.6.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 ---------------NOTE--------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A or B -------------------------------------

not met during movement of [recently] Suspend movement of Immediately irradiated fuel [recently] irradiated fuel assemblies in the assemblies in the [primary

[primary or secondary and secondary containment]. containment].

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 ------------------------------NOTES-----------------------------

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

2. Not required to be met for SCIVs that are open under administrative means.

Verify each secondary containment isolation manual [ 31 days valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed OR during accident conditions is closed.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.4.2-3 Rev. 5.0

SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.4.2.2 Verify the isolation time of each power operated, [ In accordance automatic SCIV is within limits. with the INSERVICE TESTING PROGRAM OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.4.2.3 Verify each automatic SCIV actuates to the isolation [ [18] months position on an actual or simulated automatic isolation signal. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.4.2-4 Rev. 5.0

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

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

B. Required Action and B.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met in MODE 1, 2, or 3. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> C. Required Action and --------------------NOTE-------------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not ------------------------------------------------

met during movement of

[recently] irradiated fuel C.1 Place OPERABLE SGT Immediately assemblies in the subsystem in operation.

[primary or secondary containment]. OR C.2 Suspend movement of Immediately

[recently] irradiated fuel assemblies in the [primary and secondary containment].

General Electric BWR/6 STS 3.6.4.3-1 Rev. 5.0

SGT System 3.6.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two SGT subsystems D.1 ---------------NOTE--------------

inoperable in MODE 1, LCO 3.0.4.a is not 2, or 3. applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. Two SGT subsystems E.1 ---------------NOTE--------------

inoperable during LCO 3.0.3 is not applicable.

movement of [recently] -------------------------------------

irradiated fuel assemblies in the Suspend movement of Immediately

[primary or secondary [recently] irradiated fuel containment]. assemblies in the [primary and secondary containment].

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for 15 continuous [ 31 days minutes [with heaters operating].

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.4.3-2 Rev. 5.0

SGT System 3.6.4.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with the Ventilation Filter Testing Program (VFTP). with the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual [ [18] months or simulated initiation signal, except for dampers that are locked, sealed, or otherwise secured in the OR actuated position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.6.4.3.4 [ Verify each SGT filter cooler bypass damper can [ [18] months be opened and the fan started, except for dampers that are locked, sealed, or otherwise secured in the OR open position.

In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.4.3-3 Rev. 5.0

Drywell 3.6.5.1 3.6 CONTAINMENT SYSTEMS 3.6.5.1 Drywell LCO 3.6.5.1 The drywell shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell inoperable. A.1 Restore drywell to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1.1 Verify bypass leakage is less than or equal to the [ [18] months bypass leakage limit. However, during the first unit startup following bypass leakage testing performed OR in accordance with this SR, the acceptance criterion is [10%] of the drywell bypass leakage limit. In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.1-1 Rev. 5.0

Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.1.2 Visually inspect the exposed accessible interior and [ [40] months exterior surfaces of the drywell.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.1-2 Rev. 5.0

Drywell Air Lock 3.6.5.2 3.6 CONTAINMENT SYSTEMS 3.6.5.2 Drywell Air Lock LCO 3.6.5.2 The drywell air lock shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

1. Entry and exit is permissible to perform repairs of the affected air lock components.

2. Enter applicable Conditions and Required Actions of LCO 3.6.5.1, "Drywell," when air lock leakage results in exceeding overall drywell bypass leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One drywell air lock door -------------------NOTES------------------

inoperable. 1. Required Actions A.1, A.2, and A.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls.

A.1 Verify the OPERABLE door 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is closed.

AND A.2 Lock the OPERABLE door 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> closed.

AND A.3 Verify by administrative Once per 31 days means the OPERABLE door is locked closed.

General Electric BWR/6 STS 3.6.5.2-1 Rev. 5.0

Drywell Air Lock 3.6.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Drywell air lock interlock -------------------NOTES------------------

mechanism inoperable. 1. Required Actions B.1, B.2, and B.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE door 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is closed.

AND B.2 Lock an OPERABLE door 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> closed.

AND B.3 Verify by administrative Once per 31 days means an OPERABLE door is locked closed.

C. Drywell air lock C.1 Initiate action to evaluate Immediately inoperable for reasons drywell overall leakage rate other than Condition A per LCO 3.6.5.1, "Drywell,"

or B. using current air lock test results.

AND C.2 Verify a door is closed. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND General Electric BWR/6 STS 3.6.5.2-2 Rev. 5.0

Drywell Air Lock 3.6.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.3 Restore air lock to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.2.1 -------------------------------NOTE------------------------------

Only required to be performed once after each closing.

Verify seal leakage rate is [200] scfh when the gap [ 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> between the door seals is pressurized to

[11.5] psig. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.2-3 Rev. 5.0

Drywell Air Lock 3.6.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.2.2 Verify drywell air lock seal air flask pressure is [ 7 days

[90] psig.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.5.2.3 -------------------------------NOTE------------------------------

Only required to be performed upon entry into drywell.

Verify only one door in the drywell air lock can be [ 18 months opened at a time.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.5.2.4 -------------------------------NOTE------------------------------

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

Verify overall drywell air lock leakage rate is [ 18 months

[200] scfh by performing an overall air lock leakage test at [11.5] psig. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.2-4 Rev. 5.0

Drywell Air Lock 3.6.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.2.5 Verify, from an initial pressure of [90] psig, the [ [18] months drywell air lock seal pneumatic system pressure does not decay at a rate equivalent to > [30] psig for OR a period of [10] days.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.2-5 Rev. 5.0

Drywell Isolation Valves 3.6.5.3 3.6 CONTAINMENT SYSTEMS 3.6.5.3 Drywell Isolation Valves LCO 3.6.5.3 Each drywell isolation valve [, except for Drywell Vacuum Relief System valves,] shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

1. Penetration flow paths 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 drywell isolation valves.

4. Enter applicable Conditions and Required Actions of LCO 3.6.5.1, "Drywell," when drywell isolation valve leakage results in exceeding overall drywell bypass leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> flow paths with one penetration flow path by drywell isolation valve use of at least one closed [OR inoperable. and de-activated automatic valve, closed manual valve, In accordance with blind flange, or check valve the Risk Informed with flow through the valve Completion Time secured. Program]

AND General Electric BWR/6 STS 3.6.5.3-1 Rev. 5.0

Drywell Isolation Valves 3.6.5.3 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 use of administrative means.

Verify the affected Prior to entering penetration flow path is MODE 2 or 3 from isolated. MODE 4, if not performed within the previous 92 days B. ------------NOTE------------ B.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated automatic

---

valve, closed manual valve, blind flange, or check valve One or more penetration with flow through the valve flow paths with two secured.

drywell isolation valves inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.5.3-2 Rev. 5.0

Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.3.1 [ Verify each [ ] inch drywell purge isolation valve is [ 31 days sealed closed.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.6.5.3.2 -------------------------------NOTE------------------------------

[ Not required to be met when the drywell purge supply or exhaust valves are open for pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open [provided the [20] inch containment [purge system supply and exhaust]

lines are isolated].

Verify each [20] inch drywell purge isolation valve is [ 31 days closed.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.6.5.3.3 -------------------------------NOTE------------------------------

Not required to be met for drywell isolation valves that are open under administrative controls.

Verify each drywell isolation manual valve and blind Prior to entering flange that is not locked, sealed, or otherwise MODE 2 or 3 from secured and is required to be closed during accident MODE 4, if not conditions is closed. performed in the previous 92 days General Electric BWR/6 STS 3.6.5.3-3 Rev. 5.0

Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.3.4 Verify the isolation time of each power operated, [ In accordance automatic drywell isolation valve is within limits. with the INSERVICE TESTING PROGRAM OR

[92 days]

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.5.3.5 Verify each automatic drywell isolation valve [ [18] months actuates to the isolation position on an actual or simulated isolation signal. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.5.3.6 [ Verify each [ ] inch drywell purge isolation valve is [ [18] months blocked to restrict the valve from opening > [50]%.

OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.6.5.3-4 Rev. 5.0

Drywell Pressure 3.6.5.4 3.6 CONTAINMENT SYSTEMS 3.6.5.4 Drywell Pressure LCO 3.6.5.4 Drywell-to-primary containment differential pressure shall be [ -0.26 psid and 2.0 psid].

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell-to-primary A.1 Restore drywell-to-primary 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> containment differential containment differential pressure not within pressure to within limits.

limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.4.1 Verify drywell-to-primary containment differential [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> pressure is within limits.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.4-1 Rev. 5.0

Drywell Air Temperature 3.6.5.5 3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.5 Drywell average air temperature shall be [135]F.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell average air 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> temperature not within temperature to within limit.

limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.5.1 Verify drywell average air temperature is within limit. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.5-1 Rev. 5.0

Drywell Vacuum Relief System 3.6.5.6 3.6 CONTAINMENT SYSTEMS 3.6.5.6 Drywell Vacuum Relief System LCO 3.6.5.6 [Two] drywell post-LOCA and [two] drywell purge vacuum relief subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

Enter applicable Conditions and Required Actions of LCO 3.6.5.1, "Drywell," when inoperable drywell purge vacuum relief subsystem(s) results in exceeding overall drywell bypass leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE------------ A.1 Close the subsystem. 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Separate Condition entry is allowed for each vacuum relief subsystem.

One or more vacuum relief subsystems not closed.

B. One or [two] drywell B.1 Restore drywell post-LOCA 30 days post-LOCA vacuum vacuum relief subsystem(s) relief subsystems to OPERABLE status.

inoperable for reasons other than Condition A.

C. One drywell purge C.1 Restore drywell purge 30 days vacuum relief subsystem vacuum relief subsystem to inoperable for reasons OPERABLE status.

other than Condition A.

General Electric BWR/6 STS 3.6.5.6-1 Rev. 5.0

Drywell Vacuum Relief System 3.6.5.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition B or C applicable when entering not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. [Two] drywell purge E.1 Restore one drywell purge 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> vacuum relief vacuum relief subsystem to subsystems inoperable OPERABLE status.

for reasons other than Condition A.

F. [Two] drywell post-LOCA F.1 Restore one drywell post- 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> vacuum relief LOCA vacuum relief or subsystems inoperable drywell purge vacuum relief for reasons other than subsystem to OPERABLE Condition A. status.

AND One drywell purge vacuum relief subsystem inoperable for reasons other than Condition A.

G. Required Action and G.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, E, AND or F not met.

G.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> General Electric BWR/6 STS 3.6.5.6-2 Rev. 5.0

Drywell Vacuum Relief System 3.6.5.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. [Two] drywell purge H.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> vacuum relief subsystems inoperable AND for reasons other than Condition A. H.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> AND One or [two] drywell post-LOCA vacuum relief subsystems inoperable for reasons other than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.6.1 ------------------------------NOTES-----------------------------

1. Not required to be met for drywell purge vacuum relief breakers open during Surveillances.

2. Not required to be met for vacuum breakers open when performing their intended function.

Verify each vacuum breaker and its associated [ 7 days isolation valve is closed.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.6-3 Rev. 5.0

Drywell Vacuum Relief System 3.6.5.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.6.2 Perform a functional test of each vacuum breaker [ 31 days and its associated isolation valve.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.6.5.6.3 Verify the opening setpoint of each vacuum breaker [ [18] months is [1.0] psid.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.6.5.6-4 Rev. 5.0

[SSW] System and [UHS]

3.7.1 3.7 PLANT SYSTEMS 3.7.1 [Standby Service Water (SSW)] System and [Ultimate Heat Sink (UHS)]

LCO 3.7.1 Division 1 and 2 [SSW] subsystems and [UHS] shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [ One or more cooling A.1 Restore cooling tower 7 days towers with one cooling fan(s) to OPERABLE tower fan inoperable. status. [OR In accordance with the Risk Informed Completion Time Program] ]

General Electric BWR/6 STS 3.7.1-1 Rev. 5.0

[SSW] System and [UHS]

3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One [SSW] subsystem B.1 --------------NOTES-------------

inoperable [for reasons 1. Enter applicable other than Condition A]. Conditions and Required Actions of LCO 3.8.1, "AC Sources -

Operating," for diesel generator made inoperable by [SSW].

2. Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal (RHR)

Shutdown Cooling System - Hot Shutdown," for [RHR shutdown cooling] made inoperable by [SSW].

Restore [SSW] subsystem 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.7.1-2 Rev. 5.0

[SSW] System and [UHS]

3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when entering not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

---

REVIEWERS NOTE----- D.1 Verify water temperature of Once per hour ]

The [ ]F is the maximum the UHS is [90]F allowed UHS temperature averaged over the previous value and is based on 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period.

temperature limitations of the equipment that is relied upon for accident mitigation and safe shutdown of the unit.

D. [ Water temperature of the UHS > [90]F and

[ ]F.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition D not AND met.

E.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Both [SSW] subsystems inoperable [for reasons other than Condition A].

[ OR

[UHS] inoperable for reasons other than Condition A [or D]. ]

General Electric BWR/6 STS 3.7.1-3 Rev. 5.0

[SSW] System and [UHS]

3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 [ Verify the water level of each [UHS] cooling tower [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> basin is [7.25] ft.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.7.1.2 [ Verify the water level [in each SSW pump well of [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> the intake structure] is [ ] ft.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.7.1.3 [ Verify the average water temperature of [UHS] is [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

[ ]F.

OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.7.1-4 Rev. 5.0

[SSW] System and [UHS]

3.7.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.1.4 [ Operate each [SSW] cooling tower fan for [ 31 days

[15] minutes.

OR In accordance with the Surveillance Frequency Control Program ] ]

SR 3.7.1.5 -------------------------------NOTE------------------------------

Isolation of flow to individual components does not render [SSW] System inoperable.

Verify each [SSW] subsystem manual, power [ 31 days operated, and automatic valve in the flow path servicing safety related systems or components, OR that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance Frequency Control Program ]

SR 3.7.1.6 Verify each [SSW] subsystem actuates on an actual [ [18] months or simulated initiation signal, except for valves that are locked, sealed, or otherwise secured in the OR actuated position.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.7.1-5 Rev. 5.0

HPCS SWS 3.7.2 3.7 PLANT SYSTEMS 3.7.2 High Pressure Core Spray (HPCS) Service Water System (SWS)

LCO 3.7.2 The HPCS SWS shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. HPCS SWS inoperable. A.1 Declare HPCS System Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Verify water level of the [a standby service water] [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> cooling tower basin is [7.25] ft.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.7.2-1 Rev. 5.0

HPCS SWS 3.7.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.2.2 -------------------------------NOTE------------------------------

Isolation of flow to individual components does not render [HPCS SWS] System inoperable.

Verify each HPCS SWS manual, power operated, [ 31 days and automatic valve in the flow path [servicing safety related systems or components], that is not OR locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance Frequency Control Program ]

SR 3.7.2.3 Verify the HPCS SWS actuates on an actual or [ [18] months simulated initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated OR position.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.7.2-2 Rev. 5.0

[CRFA] System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 [Control Room Fresh Air (CRFA)] System LCO 3.7.3 Two [CRFA] subsystems shall be OPERABLE.

---

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

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

APPLICABILITY: MODES 1, 2, and 3, During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One [CRFA] subsystem A.1 Restore [CRFA] subsystem 7 days inoperable for reasons to OPERABLE status.

other than Condition B.

B. One or more [CRFA] B.1 Initiate action to implement Immediately subsystems inoperable mitigating actions.

due to inoperable CRE boundary in MODE 1, 2, AND or 3.

B.2 Verify mitigating actions 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

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

General Electric BWR/6 STS 3.7.3-1 Rev. 5.0

[CRFA] System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when entering not met in MODE 1, 2, MODE 3.

or 3. -------------------------------------

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> D. Required Action and --------------------NOTE-------------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not ------------------------------------------------

met during movement of

[recently] irradiated fuel D.1 ---------------NOTE--------------

assemblies in the [ Place in toxic gas

[primary or secondary protection mode if containment]. automatic transfer to toxic gas protection mode is inoperable. ]

Place OPERABLE [CRFA] Immediately subsystem in [isolation]

mode.

OR D.2 Suspend movement of Immediately

[recently] irradiated fuel assemblies in the [primary and secondary containment].

General Electric BWR/6 STS 3.7.3-2 Rev. 5.0

[CRFA] System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two [CRFA] subsystems E.1 ---------------NOTE--------------

inoperable in MODE 1, LCO 3.0.4.a is not 2, or 3 for reasons other applicable when entering than Condition B. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> F. Two [CRFA] subsystems --------------------NOTE-------------------

inoperable during LCO 3.0.3 is not applicable.

movement of [recently] ------------------------------------------------

irradiated fuel assemblies in the F.1 Suspend movement of Immediately

[primary or secondary [recently] irradiated fuel containment]. assemblies in the [primary and secondary OR containment].

One or more [CRFA]

subsystems inoperable due to inoperable CRE boundary during movement of [recently]

irradiated fuel assemblies in the

[primary or secondary containment].

General Electric BWR/6 STS 3.7.3-3 Rev. 5.0

[CRFA] System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Operate each [CRFA] subsystem for 15 [ 31 days continuous minutes [with heaters operating].

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.7.3.2 Perform required [CRFA] filter testing in accordance In accordance with the [Ventilation Filter Testing Program (VFTP)]. with the [VFTP]

SR 3.7.3.3 Verify each [CRFA] subsystem actuates on an [ [18] months actual or simulated initiation signal, except for dampers and valves that are locked, sealed, or OR otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program ]

SR 3.7.3.4 Perform required CRE unfiltered air inleakage In accordance testing in accordance with the Control Room with the Control Envelope Habitability Program. Room Envelope Habitability Program General Electric BWR/6 STS 3.7.3-4 Rev. 5.0

[Control Room AC] System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 [Control Room Air Conditioning (AC)] System LCO 3.7.4 Two [control room AC] subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One [control room AC] A.1 Restore [control room AC] 30 days subsystem inoperable. subsystem to OPERABLE status.

B. Two [control room AC] B.1 Verify control room area Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> subsystems inoperable. temperature < [90]°F.

AND B.2 Restore one [control room 7 days AC] subsystem to OPERABLE status.

C. Required Action and C.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met in MODE 1, 2, or 3. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> General Electric BWR/6 STS 3.7.4-1 Rev. 5.0

[Control Room AC] System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and --------------------NOTE-------------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not ------------------------------------------------

met during movement of

[recently] irradiated fuel D.1 Place OPERABLE [control Immediately assemblies in the room AC] subsystem in

[primary or secondary operation.

containment].

OR D.2 Suspend movement of Immediately

[recently] irradiated fuel assemblies in the [primary and secondary containment].

E. Required Action and --------------------NOTE-------------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition B not ------------------------------------------------

met during movement of

[recently] irradiated fuel E.1 Suspend movement of Immediately assemblies in the [recently] irradiated fuel

[primary or secondary assemblies in the [primary containment]. and secondary containment].

General Electric BWR/6 STS 3.7.4-2 Rev. 5.0

[Control Room AC] System 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each [control room AC] subsystem has the [ [18] months capability to remove the assumed heat load.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.7.4-3 Rev. 5.0

Main Condenser Offgas 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Main Condenser Offgas LCO 3.7.5 The gross gamma activity rate of the noble gases measured at [the offgas recombiner effluent] shall be [380] mCi/second [after decay of 30 minutes].

APPLICABILITY: MODE 1, MODES 2 and 3 with any [main steam line not isolated and] steam jet air ejector (SJAE) in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma activity A.1 Restore gross gamma 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> rate of the noble gases activity rate of the noble not within limit. gases to within limit.

B. Required Action and B.1 [ Isolate all main steam 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ]

associated Completion lines.

Time not met.

OR B.2 Isolate SJAE. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR B.3 ---------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> General Electric BWR/6 STS 3.7.5-1 Rev. 5.0

Main Condenser Offgas 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 -------------------------------NOTE------------------------------

Not required to be performed until 31 days after any

[main steam line not isolated and] SJAE in operation.

Verify the gross gamma activity rate of the noble [ 31 days gases is [380] mCi/second [after decay of 30 minutes]. OR In accordance with the Surveillance Frequency Control Program ]

AND Once within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after a 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level General Electric BWR/6 STS 3.7.5-2 Rev. 5.0

Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Turbine Bypass System LCO 3.7.6 The Main Turbine Bypass System shall be OPERABLE.

OR The following limits are made applicable:

[ a. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," limits for an inoperable Main Turbine Bypass System, as specified in the [COLR] and ]

[ b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the

[COLR]. ]

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [Requirements of the A.1 [Satisfy the requirements of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> LCO not met or Main the LCO or restore Main Turbine Bypass System Turbine Bypass System to [OR inoperable.] OPERABLE status.]

In accordance with the Risk Informed Completion Time Program]

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to < 25% RTP.

Time not met.

General Electric BWR/6 STS 3.7.6-1 Rev. 5.0

Main Turbine Bypass System 3.7.6 SURVEILLANCE REQUIREMENTS

---

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

Not required to be met when the Main Turbine Bypass System is not required to be OPERABLE.

SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify one complete cycle of each main turbine [ 31 days bypass valve.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.7.6.2 Perform a system functional test. [ [18] months OR In accordance with the Surveillance Frequency Control Program ]

SR 3.7.6.3 Verify the TURBINE BYPASS SYSTEM [ [18] months RESPONSE TIME is within limits.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.7.6-2 Rev. 5.0

Fuel Pool Water Level 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Fuel Pool Water Level LCO 3.7.7 The fuel pool water level shall be [23] ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool and upper containment fuel storage pool racks.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel pool water level not A.1 ---------------NOTE--------------

within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the associated fuel storage pool(s).

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the fuel pool water level is [23] ft over the [ 7 days top of irradiated fuel assemblies seated in the storage racks. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.7.7-1 Rev. 5.0

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electric Power Distribution System,

b. Three diesel generators (DGs), and

[ c. Three automatic sequencers. ]

APPLICABILITY: MODES 1, 2, and 3.

---

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

[Division 3] AC electrical power sources are not required to be OPERABLE when High Pressure Core Spray System [2C Standby Service Water System] is inoperable.

ACTIONS

---

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

LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One [required] offsite A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> circuit inoperable. OPERABLE [required]

offsite circuit. AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter AND General Electric BWR/6 STS 3.8.1-1 Rev. 5.0

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2 Declare required feature(s) 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from with no offsite power discovery of no offsite available inoperable when power to one division the redundant required concurrent with feature(s) are inoperable. inoperability of redundant required feature(s)

AND A.3 Restore [required] offsite 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> circuit to OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program]

AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from discovery of two divisions with no offsite power

[OR In accordance with the Risk Informed Completion Time Program]

B. One [required] DG B.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. OPERABLE [required]

offsite circuit(s). AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter AND General Electric BWR/6 STS 3.8.1-2 Rev. 5.0

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2 Declare required feature(s), 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from supported by the inoperable discovery of DG, inoperable when the Condition B redundant required concurrent with feature(s) are inoperable. inoperability of redundant required feature(s)

AND B.3.1 Determine OPERABLE [24] hours DG(s) are not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for [24] hours OPERABLE DG(s).

AND B.4 Restore required DG to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

C. Two [required] offsite C.1 Declare required feature(s) 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from circuits inoperable. inoperable when the discovery of redundant required Condition C feature(s) are inoperable. concurrent with inoperability of redundant required feature(s)

AND General Electric BWR/6 STS 3.8.1-3 Rev. 5.0

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.2 Restore one [required] 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> offsite circuit to OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program]

D. One [required] offsite --------------------NOTE-------------------

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

when Condition D is entered with no One [required] DG AC power source to any [division].

inoperable. ------------------------------------------------

D.1 Restore [required] offsite 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> circuit to OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program]

OR D.2 Restore [required] DG to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.8.1-4 Rev. 5.0

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two [required] DGs E.1 Restore one [required] DG 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> inoperable. to OPERABLE status.

OR 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> if Division 3 DG is inoperable F. [ One [required] ----------REVIEWERS NOTE----------

[automatic load This Condition may be deleted if the sequencer] inoperable. unit design is such that any sequencer failure mode will only affect the ability of the associated DG to power its respective safety loads following a loss of offsite power independent of, or coincident with, a Design Basis Event.

F.1 Restore [required] [12] hours

[automatic load sequencer]

to OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program] ]

G. Required Action and G.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when entering C, D, E, or [F] not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> H. Three or more [required] H.1 Enter LCO 3.0.3. Immediately AC sources inoperable.

General Electric BWR/6 STS 3.8.1-5 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated [ 7 days power availability for each [required] offsite circuit.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.1.2 ------------------------------NOTES-----------------------------

1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

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

Verify each DG starts from standby conditions and [ 31 days achieves steady state voltage [3744] V and [4576] V and frequency [58.8] Hz OR and [61.2] Hz.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.1-6 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

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

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

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

Verify each DG is synchronized and loaded and [ 31 days operates for 60 minutes at a load [5450] kW and

[5740] kW for [Division 1 and 2] DGs, and OR

[3300] kW and [3500] kW for [Division 3] DG.

In accordance with the Surveillance Frequency Control Program ]

SR 3.8.1.4 Verify each day tank [and engine mounted tank] [ 31 days contains [220] gal of fuel oil for [Divisions 1 and 2]

and [220] gal for [Division 3]. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.1-7 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.5 Check for and remove accumulated water from each [ [31] days day tank [and engine mounted tank].

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.1.6 Verify the fuel oil transfer system operates to [ [92] days

[automatically] transfer fuel oil from storage tank[s]

to the day tank [and engine mounted tank]. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.1.7 -------------------------------NOTE------------------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby condition and [ 184 days achieves:

OR

a. In [10] seconds, voltage [3744] V and frequency [58.8] Hz and In accordance with the

b. Steady state voltage [3744] V and [4576] V Surveillance and frequency [58.8] Hz and [61.2] Hz. Frequency Control Program ]

General Electric BWR/6 STS 3.8.1-8 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.8 -------------------------------NOTE------------------------------

[ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ]

[ Verify [automatic and manual] transfer of [unit [ [18] months power supply] from the [normal offsite circuit to each

[required] alternate offsite circuit and between the OR

[required] alternate] offsite circuits.

In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.8.1-9 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

2. If performed with DG synchronized with offsite power, it shall be performed at a power factor

[0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.]

Verify each DG rejects a load greater than or equal [ [18] months to its associated single largest post-accident load for

[Division 1 and [550] kW for Division 2] DGs and OR

[2180] kW for [Division 3] DG, and:

In accordance

a. Following load rejection, the frequency is with the

[69] Hz, Surveillance Frequency

b. Within [3] seconds following load rejection, the Control Program ]

voltage is [3744] V and [4576] V, and

c. Within [3] seconds following load rejection, the frequency is [58.8] Hz and [61.2] Hz.

General Electric BWR/6 STS 3.8.1-10 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.10 ------------------------------NOTES-----------------------------

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

2. If performed with DG synchronized with offsite power, it shall be performed at a power factor

[0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. ]

Verify each DG does not trip and voltage is [ [18] months maintained [5000] V during and following a load rejection of a load [5450] kW and [5740] kW for OR

[Division 1 and 2] DGs and [3300] kW and

[3500] kW for [Division 3] DG. In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.1-11 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 ------------------------------NOTES-----------------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power [ [18] months signal:

OR

a. De-energization of emergency buses, In accordance

b. Load shedding from emergency buses, and with the Surveillance

c. DG auto-starts from standby condition and: Frequency Control Program ]

1. Energizes permanently connected loads in [10] seconds,

2. Energizes auto-connected shutdown loads through [automatic load sequencer],

3. Maintains steady state voltage

[3744] V and [4576] V,

4. Maintains steady state frequency [58.8]

Hz and [61.2] Hz, and

5. Supplies permanently connected and auto-connected shutdown loads for

[5] minutes.

General Electric BWR/6 STS 3.8.1-12 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ------------------------------NOTES-----------------------------

1. All DG starts may be preceded by an engine prelube period.

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

Verify on an actual or simulated Emergency Core [ [18] months Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and: OR

a. In [10] seconds after auto-start and during In accordance tests, achieves voltage [3744] V frequency with the

[58.8] Hz Surveillance Frequency

b. Achieves steady state voltage [3744] V and Control Program ]

[4576] V and frequency [58.8] Hz and

[61.2] Hz,

c. Operates for [5] minutes,

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

e. Emergency loads are energized [or auto-connected through the automatic load sequencer] to from the offsite power system.

General Electric BWR/6 STS 3.8.1-13 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

[ This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ]

Verify each DG's noncritical automatic trips are [ [18] months bypassed on [actual or simulated loss of voltage signal on the emergency bus concurrent with an OR actual or simulated ECCS initiation signal].

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.1-14 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 ------------------------------NOTES-----------------------------

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

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

3. If performed with DG synchronized with offsite power, it shall be performed at a power factor

[0.9] for Division 1 and 2 DGs, and [0.9] for Division 3 DG. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Verify each DG operates for 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: [ [18] months

a. For [2] hours loaded, [5450] kW and OR

[5740] kW for Division 1 and 2 DGs,

[3630] kW and [3830] kW for Division 3 DG In accordance and with the Surveillance

b. For the remaining hours of the test loaded Frequency

[3744] kW and [4576] kW for Division 1 Control Program ]

and 2 DGs, and [3300] kW and [3500] kW for Division 3 DG.

General Electric BWR/6 STS 3.8.1-15 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15 ------------------------------NOTES-----------------------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated [2] hours loaded [4500] kW and [5000] kW for [Division 1 and 2] DGs, and

[3300] kW and [3500] kW for Division 3 DG.

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

2. All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves: [ [18] months

a. In [10] seconds, voltage [3744] V and OR frequency [58.8] Hz and In accordance

b. Steady state voltage [3744] V and [4576] V with the and frequency [58.8] Hz and [61.2] Hz. Surveillance Frequency Control Program ]

SR 3.8.1.16 -------------------------------NOTE------------------------------

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify each DG: [ [18] months

a. Synchronizes with offsite power source while OR loaded with emergency loads upon a simulated restoration of offsite power, In accordance with the

b. Transfers loads to offsite power source, and Surveillance Frequency

c. Returns to ready-to-load operation. Control Program ]

General Electric BWR/6 STS 3.8.1-16 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

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

Verify, with a DG operating in test mode and [ [18] months connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by: OR

a. Returning DG to ready-to-load operation and In accordance with the

[ b. Automatically energizing the emergency load Surveillance from offsite power. ] Frequency Control Program ]

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

[ This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ]

[ Verify interval between each sequenced load block [ [18] months is within +/- [10% of design interval] [for each load sequencer timer]. OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.8.1-17 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 ------------------------------NOTES-----------------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of offsite [ [18] months power signal in conjunction with an actual or simulated ECCS initiation signal: OR

a. De-energization of emergency buses, In accordance with the

b. Load shedding from emergency buses, and Surveillance Frequency

c. DG auto-starts from standby condition and: Control Program ]

1. Energizes permanently connected loads in [10] seconds,

2. Energizes auto-connected emergency loads through [load sequencer],

3. Achieves steady state voltage [3744] V and [4576] V,

4. Achieves steady state frequency

[58.8] Hz and [61.2] Hz, and

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

[5] minutes.

General Electric BWR/6 STS 3.8.1-18 Rev. 5.0

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 -------------------------------NOTE------------------------------

All DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from standby [ 10 years condition, [each] [Division 1, 2, and 3] DG achieves:

OR

a. In [10] seconds, voltage [3744] V and frequency [58.8] Hz and In accordance with the

b. Steady state voltage [3744] V and [4576] V Surveillance and frequency [58.8] Hz and [61.2] Hz. Frequency Control Program ]

General Electric BWR/6 STS 3.8.1-19 Rev. 5.0

AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources - Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown,"

b. One diesel generator (DG) capable of supplying one division of the Division 1 or 2 onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10, and

c. One qualified circuit, other than the circuit in LCO 3.8.2.a, between the offsite transmission and the Division 3 onsite Class 1E electrical power distribution subsystem, or the Division 3 DG capable of supplying the Division 3 onsite Class 1E AC electrical power distribution subsystem when the Division 3 onsite Class 1E electrical power distribution subsystem is required by LCO 3.8.10.

APPLICABILITY: MODES 4 and 5, During movement of [recently] irradiated fuel assemblies in the [primary or secondary] containment.

General Electric BWR/6 STS 3.8.2-1 Rev. 5.0

AC Sources - Shutdown 3.8.2 ACTIONS

---

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. LCO Item a. not met. --------------------NOTE-------------------

Enter applicable Condition and Required Actions of LCO 3.8.10, with one required division de-energized as a result of Condition A.

A.1 Declare affected required Immediately feature(s) with no offsite power available inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately

[recently] irradiated fuel assemblies in the [primary and secondary]

containment.

AND A.2.3 Initiate action to restore Immediately required offsite power circuit to OPERABLE status.

General Electric BWR/6 STS 3.8.2-2 Rev. 5.0

AC Sources - Shutdown 3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. LCO Item b. not met. B.1 Suspend CORE Immediately ALTERATIONS.

AND B.2 Suspend movement of Immediately

[recently] irradiated fuel assemblies in [primary and secondary] containment.

AND B.3 Initiate action to restore Immediately required DG to OPERABLE status.

C. LCO Item c. not met. C.1 Declare HPCS [and 2C [72] hours Standby Service Water System] inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 ------------------------------NOTE-------------------------------

The following SRs are not required to be performed:

SR 3.8.1.3, SR 3.8.1.9, SR 3.8.1.10, SR 3.8.1.14, and SR 3.8.1.16.

The following SRs are applicable for AC sources In accordance required to be OPERABLE: with applicable SRs SR 3.8.1.1 SR 3.8.1.6 SR 3.8.1.2 SR 3.8.1.9 SR 3.8.1.3 SR 3.8.1.10 SR 3.8.1.4 SR 3.8.1.14 SR 3.8.1.5 SR 3.8.1.16 General Electric BWR/6 STS 3.8.2-3 Rev. 5.0

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

---

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

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.1 Restore fuel oil level to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> fuel oil level less than a within limits.

[7] day supply and greater than a [6] day supply.

B. One or more DGs with B.1 Restore lube oil inventory to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> lube oil inventory less within limits.

than a [7] day supply and greater than a

[6] day supply.

C. One or more DGs with C.1 Restore fuel oil total 7 days stored fuel oil total particulates to within limit.

particulates not within limit.

D. One or more DGs with D.1 Restore stored fuel oil 30 days new fuel oil properties properties to within limits.

not within limits.

General Electric BWR/6 STS 3.8.3-1 Rev. 5.0

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

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more DGs with E.1 Restore starting air receiver 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> starting air receiver pressure to [225] psig.

pressure < [225] psig and [125] psig.

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

Time not met.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains a [7] day [ 31 days supply of fuel.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.3-2 Rev. 5.0

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

SURVEILLANCE FREQUENCY SR 3.8.3.2 Verify lube oil inventory is a [7] day supply. [ 31 days OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil In accordance are tested in accordance with, and maintained within with the Diesel the limits of, the Diesel Fuel Oil Testing Program. Fuel Oil Testing Program SR 3.8.3.4 Verify each DG air start receiver pressure is [ 31 days

[225] psig.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.3.5 Check for and remove accumulated water from each [ [31] days fuel oil storage tank.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.3-3 Rev. 5.0

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The [Division 1], [Division 2], and [Division 3] DC electrical power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One [or two] battery A.1 Restore battery terminal 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> charger[s] on one voltage to greater than or subsystem inoperable. equal to the minimum established float voltage.

AND A.2 Verify battery float current Once per [12] hours

[2] amps.

AND A. 3 Restore battery charger[s] [72] hours to OPERABLE status.

[OR In accordance with the Risk Informed Completion Time Program]

[B. One [or two] batter[y][ies B.1 Restore batter[y][ies] to [2] hours on one subsystem] OPERABLE status.

inoperable. [OR In accordance with the Risk Informed Completion Time Program] ]

General Electric BWR/6 STS 3.8.4-1 Rev. 5.0

DC Sources - Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. [Division 1 or 2] DC C.1 Restore [Division 1 and 2] [2] hours electrical power DC electrical power subsystem inoperable subsystems to OPERABLE [OR for reasons other than status.

Condition A [or B]. In accordance with the Risk Informed Completion Time Program]

D. Required Action and D.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time for [Division 1 or 2] applicable when entering DC electrical power MODE 3.

subsystem for -------------------------------------

Condition A, B, or C not met. Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. [Division 3] DC electrical E.1 Declare High Pressure Immediately power subsystem Core Spray System inoperable for reasons [and 2C Standby Service other than Condition A Water System] inoperable.

[or B].

F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time for [Division 3] DC AND electrical power subsystem for F.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Condition A, B, or E not met.

General Electric BWR/6 STS 3.8.4-2 Rev. 5.0

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater than or [ 7 days equal to the minimum established float voltage.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.4.2 Verify each [required] battery charger [ [18 months supplies [400] amps at greater than or equal to the minimum established float voltage for [8] hours. OR OR In accordance with the Verify each battery charger can recharge the battery Surveillance to the fully charged state within [24] hours while Frequency supplying the largest combined demands of the Control various continuous steady state loads, after a Program ] ]

battery discharge to the bounding design basis event discharge state.

General Electric BWR/6 STS 3.8.4-3 Rev. 5.0

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.3 ------------------------------NOTES-----------------------------

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.

2. This Surveillance shall not be performed in MODE 1, 2, or 3. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, and [ [18] months maintain in OPERABLE status, the required emergency loads for the design duty cycle when OR subjected to a battery service test.

In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.4-4 Rev. 5.0

DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources - Shutdown LCO 3.8.5 [DC electrical power subsystem(s) shall be OPERABLE to support the electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown."]

[One DC electrical power subsystem shall be OPERABLE.]

---

REVIEWER'S NOTE-----------------------------------

This second option above applies for plants having a pre-ITS licensing basis (CTS) for electrical power requirements during shutdown conditions that required only one DC electrical power subsystem to be OPERABLE.

Action A and the bracketed optional wording in Condition B are also eliminated for this case. The first option above is adopted for plants that have a CTS requiring the same level of DC electrical power subsystem support as is required for power operating conditions.

APPLICABILITY: MODES 4 and 5, During movement of [recently] irradiated fuel assemblies in the [primary or secondary] containment.

ACTIONS

---

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME

[ A. One [or two] battery A.1 Restore battery terminal 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> charger[s on one voltage to greater than or subsystem] inoperable. equal to the minimum established float voltage.

AND AND The redundant subsystem battery and A.2 Verify battery float current Once per [12] hours charger[s] OPERABLE. [2] amps.

AND General Electric BWR/6 STS 3.8.5-1 Rev. 5.0

DC Sources - Shutdown 3.8.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.3 Restore battery charger[s] [72] hours ]

to OPERABLE status.

B. One [or more] required B.1 Declare affected required Immediately DC electrical power feature(s) inoperable.

subsystem[s] inoperable

[for reasons other than OR Condition A.

B.2.1 Suspend CORE Immediately OR ALTERATIONS.

Required Action and AND associated Completion Time of Condition A not B.2.2 Suspend movement of Immediately met.] [recently] irradiated fuel assemblies in the [primary or secondary] containment.

AND B.2.3 Initiate action to restore Immediately required DC electrical power subsystems to OPERABLE status.

General Electric BWR/6 STS 3.8.5-2 Rev. 5.0

DC Sources - Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 -------------------------------NOTE------------------------------

The following SRs are not required to be performed:

SR 3.8.4.2 and SR 3.8.4.3.

For DC sources required to be OPERABLE, the In accordance following SRs are applicable: with applicable SRs SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 General Electric BWR/6 STS 3.8.5-3 Rev. 5.0

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.8.6 Battery parameters for the [Division 1, 2, and 3] electrical power subsystem batteries shall be within limits.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

---

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

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One [or two] batter[y][ies A.1 Perform SR 3.8.4.1. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> on one subsystem] with one or more battery cells AND float voltage < [2.07] V.

A.2 Perform SR 3.8.6.1. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND A.3 Restore affected cell 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> voltage [2.07] V.

B. One [or two] batter[y][ies B.1 Perform SR 3.8.4.1. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> on one subsystem] with float current > [2] amps. AND B.2 Restore battery float current [12] hours to [2] amps.

General Electric BWR/6 STS 3.8.6-1 Rev. 5.0

Battery Parameters 3.8.6 ACTIONS (continued)

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

Required Action C.2 Required Actions C.1 and C.2 are shall be completed if only applicable if electrolyte level electrolyte level was was below the top of plates.

below the top of plates. ------------------------------------------------

C.1 Restore electrolyte level to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> One [or two] batter[y][ies above top of plates.

on one subsystem] with one or more cells AND electrolyte level less than minimum C.2 Verify no evidence of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> established design leakage.

limits.

AND C.3 Restore electrolyte level to 31 days greater than or equal to minimum established design limits.

D. One [or two] batter[y][ies D.1 Restore battery pilot cell 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> on one subsystem] with temperature to greater than pilot cell electrolyte or equal to minimum temperature less than established design limits.

minimum established design limits.

E. One or more batteries in E.1 Restore battery parameters 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> redundant subsystems for batteries in one with battery parameters subsystem to within limits.

not within limits.

General Electric BWR/6 STS 3.8.6-2 Rev. 5.0

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Declare associated battery Immediately associated Completion inoperable.

Time of Condition A, B, C, D, or E not met.

OR One [or two] batter[y][ies on one subsystem] with one or more battery cells float voltage < [2.07] V and float current

> [2] amps.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 -------------------------------NOTE------------------------------

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

Verify each battery float current is [2] amps. [ 7 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.6-3 Rev. 5.0

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify each battery pilot cell float voltage is [ 31 days

[2.07] V.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.6.3 Verify each battery connected cell electrolyte level is [ 31 days greater than or equal to minimum established design limits. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.6.4 Verify each battery pilot cell temperature is greater [ 31 days than or equal to minimum established design limits.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.8.6.5 Verify each battery connected cell float voltage is [ 92 days

[2.07] V.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.6-4 Rev. 5.0

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.6 -------------------------------NOTE------------------------------

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

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

Verify battery capacity is [80%] of the [ 60 months manufacturer's rating when subjected to a performance discharge test or a modified OR performance discharge test.

In accordance with the Surveillance Frequency Control Program ]

AND 12 months when battery shows degradation, or has reached

[85]% of the expected life with capacity < 100%

of manufacturer's rating AND 24 months when battery has reached [85]% of the expected life with capacity 100% of manufacturer's rating General Electric BWR/6 STS 3.8.6-5 Rev. 5.0

Inverters - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters - Operating LCO 3.8.7 The [Division 1], [Division 2], and [Division 3] inverters shall be OPERABLE.

---

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

[ [One/two] inverter[s] may be disconnected from [its/their] associated DC bus for [24] hours to perform an equalizing charge on [its/their]

associated [common] battery, provided:

a. The associated AC vital bus[es] [is/are] energized from [its/their]

[Class 1E constant voltage transformers] [inverter using internal AC source] and

b. All other AC vital buses are energized from their associated OPERABLE inverters. ]

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [Division 1 or 2] inverter A.1 ---------------NOTE--------------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any AC vital bus de-energized.

Restore [Division 1 and 2] 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inverters to OPERABLE status. [OR In accordance with the Risk Informed Completion Time Program]

General Electric BWR/6 STS 3.8.7-1 Rev. 5.0

Inverters - Operating 3.8.7 ACTIONS (continued)

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

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> C. [ [Division 3] inverter C.1 Declare High Pressure Immediately ]

inoperable. Core Spray System [and 2C Standby Service Water System] inoperable.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition C not AND met.

D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, [frequency,] and [ 7 days alignment to required AC vital buses.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.7-2 Rev. 5.0

Inverters - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters - Shutdown LCO 3.8.8 [Inverter(s) shall be OPERABLE to support the onsite Class 1E AC vital bus electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown."]

[One] inverter[s] shall be OPERABLE.]

---

REVIEWER'S NOTE-----------------------------------

This second option above applies for plants having a pre-ITS licensing basis (CTS) for electrical power requirements during shutdown conditions that required only [one] inverter to be OPERABLE. The "[or more]"

optional wording in Condition A is also eliminated for this case. The first option above is adopted for plants that have a CTS requiring the same level of DC electrical power subsystem/inverter support as is required for power operating conditions.

APPLICABILITY: MODES 4 and 5, During movement of [recently] irradiated fuel assemblies in the [primary or secondary] containment.

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 inverter[s] inoperable. feature(s) inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND General Electric BWR/6 STS 3.8.8-1 Rev. 5.0

Inverters - Shutdown 3.8.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.2 Suspend handling of Immediately

[recently] irradiated fuel assemblies in the [primary or secondary] containment.

AND A.2.3 Initiate action to restore Immediately required inverters to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, [frequency,] and [ 7 days alignments to [required] AC vital buses.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.8-2 Rev. 5.0

Distribution Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems - Operating LCO 3.8.9 [Division 1], [Division 2], and [Division 3] AC, DC, [and AC vital bus]

electrical power distribution subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more [Division 1 A.1 ---------------NOTE--------------

and 2] AC electrical Enter applicable Conditions power distribution and Required Actions of subsystems inoperable. LCO 3.8.4, "DC Sources -

Operating," for DC trains made inoperable by inoperable power distribution subsystems.

Restore [Division 1 and 2] 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AC electrical power distribution subsystem(s) to [OR OPERABLE status.

In accordance with the Risk Informed Completion Time Program]

B. [ One or more [Division 1 B.1 Restore [Division 1 and 2] 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and 2] AC vital buses AC vital bus distribution inoperable. subsystem(s) to [OR OPERABLE status.

In accordance with the Risk Informed Completion Time Program] ]

General Electric BWR/6 STS 3.8.9-1 Rev. 5.0

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more [Division 1 C.1 Restore [Division 1 and 2] 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and 2] DC electrical DC electrical power power distribution distribution subsystem(s) to [OR subsystems inoperable. OPERABLE status.

In accordance with the Risk Informed Completion Time Program]

D. Required Action and D.1 ---------------NOTE--------------

associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when entering or C not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. One or more [Division 3] E.1 Declare High Pressure Immediately AC, DC, or AC vital bus Core Spray System [and electrical power 2C Standby Service Water distribution subsystems System] inoperable.

inoperable.

F. Two or more electrical F.1 Enter LCO 3.0.3. Immediately power distribution subsystems inoperable that result in a loss of function.

General Electric BWR/6 STS 3.8.9-2 Rev. 5.0

Distribution Systems - Operating 3.8.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to [ 7 days

[required] AC, DC, [and AC vital bus] electrical power distribution subsystems. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.9-3 Rev. 5.0

Distribution Systems - Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems - Shutdown LCO 3.8.10 The necessary portions of the Division 1, Division 2, and Division 3 AC, DC, [and AC vital bus] electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 4 and 5, During movement of [recently] irradiated fuel assemblies in the [primary or secondary] containment.

ACTIONS

---

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC, DC, [or AC vital bus] supported required electrical power feature(s) inoperable.

distribution subsystems inoperable. OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend handling of Immediately

[recently] irradiated fuel assemblies in the [primary or secondary] containment.

AND General Electric BWR/6 STS 3.8.10-1 Rev. 5.0

Distribution Systems - Shutdown 3.8.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.3 Initiate actions to restore Immediately

[required] AC, DC, [and AC vital bus] electrical power distribution subsystems to OPERABLE status.

AND A.2.4 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to [ 7 days

[required] AC, DC, [and AC vital bus] electrical power distribution subsystems. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.8.10-2 Rev. 5.0

Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks LCO 3.9.1 The refueling equipment interlocks shall be OPERABLE.

APPLICABILITY: During in-vessel fuel movement with equipment associated with the interlocks.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend in-vessel fuel Immediately refueling equipment movement with equipment interlocks inoperable. associated with the inoperable interlock(s).

OR A.2.1 Insert a control rod Immediately withdrawal block.

AND A.2.2 Verify all control rods are Immediately fully inserted.

General Electric BWR/6 STS 3.9.1-1 Rev. 5.0

Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of [ 7 days the following required refueling equipment interlock inputs: OR

a. All-rods-in, In accordance with the

b. Refuel platform position, and Surveillance Frequency

c. Refuel platform [main] hoist, fuel loaded. Control Program ]

General Electric BWR/6 STS 3.9.1-2 Rev. 5.0

Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.

APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one-rod- A.1 Suspend control rod Immediately out interlock inoperable. withdrawal.

AND A.2 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel position. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.2-1 Rev. 5.0

Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.2.2 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST. [ 7 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.2-2 Rev. 5.0

Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted.

APPLICABILITY: When loading fuel assemblies into the core.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control A.1 Suspend loading fuel Immediately rods not fully inserted. assemblies into the core.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.3-1 Rev. 5.0

Control Rod Position Indication 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Control Rod Position Indication LCO 3.9.4 One control rod "full-in" position indication channel for each control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS

---

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

Separate Condition entry is allowed for each required channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1.1 Suspend in-vessel fuel Immediately control rod position movement.

indication channels inoperable. AND A.1.2 Suspend control rod Immediately withdrawal.

AND A.1.3 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies.

OR A.2.1 Initiate action to fully insert Immediately the control rod associated with the inoperable position indicator.

AND General Electric BWR/6 STS 3.9.4-1 Rev. 5.0

Control Rod Position Indication 3.9.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.2 Initiate action to disarm the Immediately control rod drive associated with the fully inserted control rod.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify the required channel has no "full-in" indication Each time the on each control rod that is not "full-in." control rod is withdrawn from the "full-in" position General Electric BWR/6 STS 3.9.4-2 Rev. 5.0

Control Rod OPERABILITY - Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY - Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to fully insert Immediately control rods inoperable. inoperable withdrawn control rods.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 -------------------------------NOTE------------------------------

Not required to be performed until 7 days after the control rod is withdrawn.

Insert each withdrawn control rod at least one notch. [ 7 days OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.5-1 Rev. 5.0

Control Rod OPERABILITY - Refueling 3.9.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.5.2 Verify each withdrawn control rod scram [ 7 days accumulator pressure is [1520] psig.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.5-2 Rev. 5.0

[RPV] Water Level [- Irradiated Fuel]

3.9.6 3.9 REFUELING OPERATIONS 3.9.6 [Reactor Pressure Vessel (RPV)] Water Level [- Irradiated Fuel]

LCO 3.9.6 [RPV] water level shall be [22 ft 8 inches] above the top of the [RPV flange].

APPLICABILITY: During movement of irradiated fuel assemblies within the [RPV],

[ During movement of new fuel assemblies or handling of control rods within the [RPV], when irradiated fuel assemblies are seated within the [RPV]. ]

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [RPV] water level not A.1 Suspend movement of fuel Immediately within limit. assemblies and handling of control rods within the

[RPV].

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify [RPV] water level is [22 ft 8 inches] above [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> the top of the [RPV flange].

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.6-1 Rev. 5.0

[RPV] Water Level - New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 [Reactor Pressure Vessel (RPV)] Water Level - New Fuel or Control Rods LCO 3.9.7 [RPV] water level shall be [22 ft 8 inches] above the top of irradiated fuel assemblies seated within the [RPV].

APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the [RPV] when irradiated fuel assemblies are seated within the [RPV].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. [RPV] water level not A.1 Suspend movement of fuel Immediately within limit. assemblies and handling of control rods within the

[RPV].

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify [RPV] water level is [22 ft 8 inches] above [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> the top of irradiated fuel assemblies seated within the [RPV]. OR In accordance with the Surveillance Frequency Control Program ] ]

General Electric BWR/6 STS 3.9.7-1 Rev. 5.0

RHR - High Water Level 3.9.8 3.9 REFUELING OPERATIONS 3.9.8 Residual Heat Removal (RHR) - High Water Level LCO 3.9.8 One RHR shutdown cooling subsystem shall be OPERABLE and in operation.

---

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

The required RHR shutdown cooling subsystem may be removed from operation for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and with the water level [22 ft 8 inches] above the top of the [RPV flange].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required RHR shutdown A.1 Verify an alternate method 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> cooling subsystem of decay heat removal is inoperable. available. AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter B. Required Action and B.1 Suspend loading irradiated Immediately associated Completion fuel assemblies into the Time of Condition A not RPV.

met.

AND B.2 Initiate action to restore Immediately

[primary or secondary]

containment to OPERABLE status.

AND General Electric BWR/6 STS 3.9.8-1 Rev. 5.0

RHR - High Water Level 3.9.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.3 Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.

AND B.4 Initiate action to restore Immediately isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor coolant 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery cooling subsystem in circulation by an alternate of no reactor coolant operation. method. circulation AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND C.2 Monitor reactor coolant Once per hour temperature.

General Electric BWR/6 STS 3.9.8-2 Rev. 5.0

RHR - High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> operating.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.9.8.2 Verify required RHR shutdown cooling subsystem [ 31 days locations susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.8-3 Rev. 5.0

RHR - Low Water Level 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Residual Heat Removal (RHR) - Low Water Level LCO 3.9.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and one RHR shutdown cooling subsystem shall be in operation.

---

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

The required operating shutdown cooling subsystem may be removed from operation for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and with the water level < [23] ft above the top of the [RPV flange].

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Verify an alternate method 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> shutdown cooling of decay heat removal is subsystems inoperable. available for each AND inoperable RHR shutdown cooling subsystem. Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter B. Required Action and B.1 Initiate action to restore Immediately associated Completion [primary or secondary]

Time of Condition A not containment to OPERABLE met. status.

AND B.2 Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.

AND General Electric BWR/6 STS 3.9.9-1 Rev. 5.0

RHR - Low Water Level 3.9.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.3 Initiate action to restore Immediately isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor coolant 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery cooling subsystem in circulation by an alternate of no reactor coolant operation. method. circulation AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND C.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify one RHR shutdown cooling subsystem is [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> operating.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.9-2 Rev. 5.0

RHR - Low Water Level 3.9.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.9.2 Verify RHR shutdown cooling subsystem locations [ 31 days susceptible to gas accumulation are sufficiently filled with water. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.9.9-3 Rev. 5.0

Inservice Leak and Hydrostatic Testing Operation 3.10.1 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testing Operation LCO 3.10.1 The average reactor coolant temperature specified in Table 1.1-1 for MODE 4 may be changed to "NA," and operation considered not to be in MODE 3; and the requirements of LCO 3.4.10, "Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown," may be suspended to allow reactor coolant temperature > 200°F:

• For performance of an inservice leak or hydrostatic test,

• As a consequence of maintaining adequate pressure for an inservice leak or hydrostatic test, or

• As a consequence of maintaining adequate pressure for control rod scram time testing initiated in conjunction with an inservice leak or hydrostatic test.

provided the following MODE 3 LCOs are met:

a. LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation,"

[Functions 1, 3, 4, and 5] of Table 3.3.6.2-1,

b. LCO 3.6.4.1, "[Secondary Containment],"

c. LCO 3.6.4.2, "Secondary Containment Isolation Valves (SCIVs),"

and

d. LCO 3.6.4.3, "Standby Gas Treatment (SGT) System."

APPLICABILITY: MODE 4 with average reactor coolant temperature > [200]F.

General Electric BWR/6 STS 3.10.1-1 Rev. 5.0

Inservice Leak and Hydrostatic Testing Operation 3.10.1 ACTIONS

---

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 ---------------NOTE--------------

above requirements not Required Actions to be in met. MODE 4 include reducing average reactor coolant temperature to [200]F.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Suspend activities that Immediately could increase the average reactor coolant temperature or pressure.

AND A.2.2 Reduce average reactor 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> coolant temperature to

[200]F.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.1.1 Perform the applicable SRs for the required According to the MODE 3 LCOs. applicable SRs General Electric BWR/6 STS 3.10.1-2 Rev. 5.0

Reactor Mode Switch Interlock Testing 3.10.2 3.10 SPECIAL OPERATIONS 3.10.2 Reactor Mode Switch Interlock Testing LCO 3.10.2 The reactor mode switch position specified in Table 1.1-1 (Section 1.1, Definitions) for MODES 3, 4, and 5 may be changed to include the run, startup/hot standby, and refuel position, and operation considered not to be in MODE 1 or 2, to allow testing of instrumentation associated with the reactor mode switch interlock functions, provided:

a. All control rods remain fully inserted in core cells containing one or more fuel assemblies and

b. No CORE ALTERATIONS are in progress.

APPLICABILITY: MODES 3 and 4 with the reactor mode switch in the run, startup/hot standby, or refuel position, MODE 5 with the reactor mode switch in the run or startup/hot standby position.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend CORE Immediately above requirements not ALTERATIONS except for met. control rod insertion.

AND A.2 Fully insert all insertable 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> control rods in core cells containing one or more fuel assemblies.

AND A.3.1 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.

OR General Electric BWR/6 STS 3.10.2-1 Rev. 5.0

Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.3.2 ---------------NOTE--------------

Only applicable in MODE 5.

Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the refuel position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted in core cells [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> containing one or more fuel assemblies.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.2-2 Rev. 5.0

Single Control Rod Withdrawal - Hot Shutdown 3.10.3 3.10 SPECIAL OPERATIONS 3.10.3 Single Control Rod Withdrawal - Hot Shutdown LCO 3.10.3 The reactor mode switch position specified in Table 1.1-1 for MODE 3 may be changed to include the refuel position, and operation considered not to be in MODE 2, to allow withdrawal of a single control rod, provided the following requirements are met:

a. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock,"

b. LCO 3.9.4, "Control Rod Position Indication,"

c. All other control rods are fully inserted, and d.1. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation,"

MODE 5 requirements for Functions [1.a, 1.b, 2.a, 2.d, 8.a, 8.b, 11, and 12] of Table 3.3.1.1-1 and LCO 3.9.5, "Control Rod OPERABILITY - Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed, and LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 5 requirements, except the single control rod to be withdrawn may be assumed to be the highest worth control rod.

APPLICABILITY: MODE 3 with the reactor mode switch in the refuel position.

General Electric BWR/6 STS 3.10.3-1 Rev. 5.0

Single Control Rod Withdrawal - Hot Shutdown 3.10.3 ACTIONS

---

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 --------------NOTES-------------

above requirements not 1. Required Actions to fully met. insert all insertable control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to fully insert Immediately all insertable control rods.

AND A.2.2 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs General Electric BWR/6 STS 3.10.3-2 Rev. 5.0

Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.3.2 -------------------------------NOTE------------------------------

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.

Verify all control rods, other than the control rod [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.10.3.3 Verify all control rods, other than the control rod [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> being withdrawn, are fully inserted.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.3-3 Rev. 5.0

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 3.10 SPECIAL OPERATIONS 3.10.4 Single Control Rod Withdrawal - Cold Shutdown LCO 3.10.4 The reactor mode switch position specified in Table 1.1-1 for MODE 4 may be changed to include the refuel position, and operation considered not to be in MODE 2, to allow withdrawal of a single control rod, and subsequent removal of the associated control rod drive (CRD) if desired, provided the following requirements are met:

a. All other control rods are fully inserted, b.1. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock," and LCO 3.9.4, "Control Rod Position Indication,"

OR

2. A control rod withdrawal block is inserted, and c.1. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation,"

MODE 5 requirements for Functions [1.a, 1.b, 2.a, 2.d, 8.a, 8.b, 11, and 12] of Table 3.3.1.1-1 and LCO 3.9.5, "Control Rod OPERABILITY - Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed and LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 5 requirements, except the single control rod to be withdrawn may be assumed to be the highest worth control rod.

APPLICABILITY: MODE 4 with the reactor mode switch in the refuel position.

General Electric BWR/6 STS 3.10.4-1 Rev. 5.0

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS

---

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 --------------NOTES-------------

above requirements not 1. Required Actions to fully met with the affected insert all insertable control rod insertable. control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to fully insert Immediately all insertable control rods.

AND A.2.2 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.

B. One or more of the B.1 Suspend withdrawal of the Immediately above requirements not control rod and removal of met with the affected associated CRD.

control rod not insertable. AND B.2.1 Initiate action to fully insert Immediately all control rods.

OR General Electric BWR/6 STS 3.10.4-2 Rev. 5.0

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2.2 Initiate action to satisfy the Immediately requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to applicable SRs SR 3.10.4.2 -------------------------------NOTE------------------------------

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.

Verify all control rods, other than the control rod [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.10.4.3 Verify all control rods, other than the control rod [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> being withdrawn, are fully inserted.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.4-3 Rev. 5.0

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.4.4 -------------------------------NOTE------------------------------

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.

Verify a control rod withdrawal block is inserted. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.4-4 Rev. 5.0

Single CRD Removal - Refueling 3.10.5 3.10 SPECIAL OPERATIONS 3.10.5 Single Control Rod Drive (CRD) Removal - Refueling LCO 3.10.5 The requirements of LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," LCO 3.3.8.2, "Reactor Protection System (RPS) Electric Power Monitoring," LCO 3.9.1, "Refueling Equipment Interlocks,"

LCO 3.9.2, "Refuel Position One-Rod-Out Interlock," LCO 3.9.4, "Control Rod Position Indication," and LCO 3.9.5, "Control Rod OPERABILITY -

Refueling," may be suspended in MODE 5 to allow the removal of a single CRD associated with a control rod withdrawn from a core cell containing one or more fuel assemblies, provided the following requirements are met:

a. All other control rods are fully inserted,

b. All other control rods in a five by five array centered on the withdrawn control rod are disarmed,

c. A control rod withdrawal block is inserted and LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 5 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod, and

d. No other CORE ALTERATIONS are in progress.

APPLICABILITY: MODE 5 with LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend removal of the Immediately above requirements not CRD mechanism.

met.

AND A.2.1 Initiate action to fully inset Immediately all control rods.

OR General Electric BWR/6 STS 3.10.5-1 Rev. 5.0

Single CRD Removal - Refueling 3.10.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.2.2 Initiate action to satisfy the Immediately requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all controls rods, other than the control rod [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> withdrawn for the removal of the associated CRD, are fully inserted. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.10.5.2 Verify all control rods, other than the control rod [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> withdrawn for the removal of the associated CRD, in a five by five array centered on the control rod OR withdrawn for the removal of the associated CRD, are disarmed. In accordance with the Surveillance Frequency Control Program ]

SR 3.10.5.3 Verify a control rod withdrawal block is inserted. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.5-2 Rev. 5.0

Single CRD Removal - Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.5.5 Verify no CORE ALTERATIONS are in progress. [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.5-3 Rev. 5.0

Multiple Control Rod Withdrawal - Refueling 3.10.6 3.10 SPECIAL OPERATIONS 3.10.6 Multiple Control Rod Withdrawal - Refueling LCO 3.10.6 The requirements of LCO 3.9.3, "Control Rod Position," LCO 3.9.4, "Control Rod Position Indication," and LCO 3.9.5, "Control Rod OPERABILITY - Refueling," may be suspended, and the "full in" position indicators may be bypassed for any number of control rods in MODE 5, to allow withdrawal of these control rods, removal of associated control rod drives (CRDs), or both, provided the following requirements are met:

a. The four fuel assemblies are removed from the core cells associated with each control rod or CRD to be removed,

b. All other control rods in core cells containing one or more fuel assemblies are fully inserted, and

c. Fuel assemblies shall only be loaded in compliance with an approved [spiral] reload sequence.

APPLICABILITY: MODE 5 with LCO 3.9.3, LCO 3.9.4, or LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend withdrawal of Immediately above requirements not control rods and removal of met. associated CRDs.

AND A.2 Suspend loading fuel Immediately assemblies.

AND A.3.1 Initiate action to fully insert Immediately all control rods in core cells containing one or more fuel assemblies.

OR General Electric BWR/6 STS 3.10.6-1 Rev. 5.0

Multiple Control Rod Withdrawal - Refueling 3.10.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.3.2 Initiate action to satisfy the Immediately requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1 Verify the four fuel assemblies are removed from [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> core cells associated with each control rod or CRD removed. OR In accordance with the Surveillance Frequency Control Program ]

SR 3.10.6.2 Verify all other control rods in core cells containing [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> one or more fuel assemblies are fully inserted.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.6-2 Rev. 5.0

Multiple Control Rod Withdrawal - Refueling 3.10.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.6.3 -------------------------------NOTE------------------------------

Only required to be met during fuel loading.

Verify fuel assemblies being loaded are in [ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> compliance with an approved [spiral] reload sequence. OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.6-3 Rev. 5.0

Control Rod Testing - Operating 3.10.7 3.10 SPECIAL OPERATIONS 3.10.7 Control Rod Testing - Operating LCO 3.10.7 The requirements of LCO 3.1.6, "Rod Pattern Control," may be suspended and control rods bypassed in the Rod Action Control System as allowed by SR 3.3.2.1.8, to allow performance of SDM demonstrations, control rod scram time testing, control rod friction testing, and the Startup Test Program, provided conformance to the approved control rod sequence for the specified test is verified by a second licensed operator or other qualified member of the technical staff.

APPLICABILITY: MODES 1 and 2 with LCO 3.1.6 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Suspend performance of Immediately LCO not met. the test and exception to LCO 3.1.6.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.1 Verify movement of control rods is in compliance During control rod with the approved control rod sequence for the movement specified test by a second licensed operator or other qualified member of the technical staff.

General Electric BWR/6 STS 3.10.7-1 Rev. 5.0

SDM Test - Refueling 3.10.8 3.10 SPECIAL OPERATIONS 3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling LCO 3.10.8 The reactor mode switch position specified in Table 1.1-1 for MODE 5 may be changed to include the startup/hot standby position, and operation considered not to be in MODE 2, to allow SDM testing, provided the following requirements are met:

a. LCO 3.3.1.1, "Reactor Protection System Instrumentation," MODE 2 requirements for Function 2.a and 2.d of Table 3.3.1.1-1, b.1. LCO 3.3.2.1, "Control Rod Block Instrumentation," MODE 2 requirements for Function 1.b of Table 3.3.2.1-1, OR

2. Conformance to the approved control rod sequence for the SDM test is verified by a second licensed operator or other qualified member of the technical staff,

c. Each withdrawn control rod shall be coupled to the associated CRD,

d. All control rod withdrawals [during out of sequence control rod moves] shall be made in single notch withdrawal mode,

e. No other CORE ALTERATIONS are in progress, and

f. CRD charging water header pressure [1520] psig.

APPLICABILITY: MODE 5 with the reactor mode switch in startup/hot standby position.

General Electric BWR/6 STS 3.10.8-1 Rev. 5.0

SDM Test - Refueling 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE------------ --------------------NOTE-------------------

Separate Condition entry Inoperable control rods may be is allowed for each bypassed in accordance with control rod. SR 3.3.2.1.9, if required, to allow

---

insertion of inoperable control rod and continued operation.

One or more control ------------------------------------------------

rods not coupled to its associated CRD. A.1 Fully insert inoperable 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> CRD.

B. One or more of the B.1 Place the reactor mode Immediately above requirements not switch in the shutdown or met, for reasons other refuel position.

than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for According to the LCO 3.3.1.1, Functions 2.a and 2.d of applicable SRs Table 3.3.1.1-1.

SR 3.10.8.2 -------------------------------NOTE------------------------------

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for According to the LCO 3.3.2.1, Function 1.b of Table 3.3.2.1-1. applicable SRs General Electric BWR/6 STS 3.10.8-2 Rev. 5.0

SDM Test - Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.3 -------------------------------NOTE------------------------------

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in compliance During control with the approved control rod sequence for the SDM rod movement test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in [ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> progress.

OR In accordance with the Surveillance Frequency Control Program ]

SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. control rod is withdrawn to "full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling General Electric BWR/6 STS 3.10.8-3 Rev. 5.0

SDM Test - Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.6 Verify CRD charging water header pressure [ 7 days 1520 psig.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.8-4 Rev. 5.0

Recirculation Loops - Testing 3.10.9 3.10 SPECIAL OPERATIONS 3.10.9 Recirculation Loops - Testing LCO 3.10.9 The requirements of LCO 3.4.1, "Recirculation Loops Operating," may be suspended for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> to allow:

a. PHYSICS TESTS, provided THERMAL POWER is [5]% RTP and

b. Performance of the Startup Test Program.

APPLICABILITY: MODES 1 and 2 with less than two recirculation loops in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of A.1 Insert all insertable control [1] hour LCO 3.4.1 not met for rods.

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

B. Requirements of the B.1 Place the reactor mode Immediately LCO not met for reasons switch in the shutdown other than Condition A. position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.9.1 Verify LCO 3.4.1 requirements suspended for [ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 24 hours.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.9-1 Rev. 5.0

Recirculation Loops - Testing 3.10.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.9.2 Verify THERMAL POWER is [5]% RTP during [ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> PHYSICS TESTS.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.9-2 Rev. 5.0

Training Startups 3.10.10 3.10 SPECIAL OPERATIONS 3.10.10 Training Startups LCO 3.10.10 The low pressure coolant injection (LPCI) OPERABILITY requirements specified in LCO 3.5.1, "ECCS - Operating," may be changed to allow one residual heat removal subsystem to be aligned in the shutdown cooling mode for training startups, provided the following requirements are met:

a. All OPERABLE intermediate range monitor (IRM) channels are

[25/40] divisions of full scale on Range 7 and

b. Average reactor coolant temperature is < 200F.

APPLICABILITY: MODE 2 with one LPCI subsystem suction valve closed.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Place the reactor mode Immediately above requirements not switch in the shutdown met. position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.10.1 Verify all OPERABLE IRM channels are [25/40] [ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> divisions of full scale on Range 7.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.10-1 Rev. 5.0

Training Startups 3.10.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.10.2 Verify average reactor coolant temperature is [ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />

< 200F.

OR In accordance with the Surveillance Frequency Control Program ]

General Electric BWR/6 STS 3.10.10-2 Rev. 5.0

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location

[ Text description of site location. ]

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain [800] fuel assemblies. Each assembly shall consist of a matrix of [Zircalloy or ZIRLO] fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO2) as fuel material and [water rods]. Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used.

Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain [193] cruciform shaped control rod assemblies.

The control material shall be [boron carbide, hafnium metal] as approved by the NRC.

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 [k-infinity of [1.31] in the normal reactor core configuration at cold conditions] [average U-235 enrichment of [4.5] weight percent],

b. keff 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in [Section 9.1 of the FSAR],

c. [ A nominal fuel assembly center to center storage spacing of

[7] inches within rows and [12.25] inches between rows in the [low density storage racks] in the upper containment pool, and ]

d. [ A nominal fuel assembly center to center storage spacing of

[6.26] inches, within a neutron poison material between storage spaces, in the [high density storage racks] in the spent fuel storage pool and in the upper containment pool. ]

General Electric BWR/6 STS 4.0-1 Rev. 5.0

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum [k-infinity of [1.31] in the normal reactor core configuration at cold conditions] [average U-235 enrichment of [4.5] weight percent],

b. keff 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in [Section 9.1 of the FSAR],

c. keff 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in [Section 9.1 of the FSAR], and

d. A nominal [6.26] inch center to center distance between fuel assemblies placed in storage racks.

4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation [202 ft 5.25 inches].

4.3.3 Capacity 4.3.3.1 The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than [2324] fuel assemblies.

4.3.3.2 No more than [800] fuel assemblies may be stored in the upper containment pool.

General Electric BWR/6 STS 4.0-2 Rev. 5.0

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility

---

REVIEWER'S NOTES------------------------------------------------

1. Titles for members of the unit staff shall be specified by use of an overall statement referencing an ANSI Standard acceptable to the NRC staff from which the titles were obtained, or an alternative title may be designated for this position. Generally, the first method is preferable; however, the second method is adaptable to those unit staffs requiring special titles because of unique organizational structures.

2. The ANSI Standard shall be the same ANSI Standard referenced in Section 5.3, Unit Staff Qualifications. If alternative titles are used, all requirements of these Technical Specifications apply to the position with the alternative title as apply with the specified title.

Unit staff titles shall be specified in the Final Safety Analysis Report or Quality Assurance Plan. Unit staff titles shall be maintained and revised using those procedures approved for modifying/revising the Final Safety Analysis Report or Quality Assurance Plan.

5.1.1 The plant manager shall be responsible for overall unit operation 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 Supervisor (SS)] shall be responsible for the control room command function. During any absence of the [SS] from the control room while the unit is in MODE 1, 2, or 3, 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 [SS] from the control room while the unit is in MODE 4 or 5, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

General Electric BWR/6 STS 5.1-1 Rev. 5.0

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/QA Plan],

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 health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

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 MODES 1, 2, or 3.

---

REVIEWER'S NOTE----------------------------------------

Two unit sites with both units shutdown or defueled require a total of three non-licensed operators for the two units.

General Electric BWR/6 STS 5.2-1 Rev. 5.0

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

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 be exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 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.

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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, 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.

General Electric BWR/6 STS 5.2-2 Rev. 5.0

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications

---

REVIEWER'S NOTE-------------------------------------------------

Minimum qualifications for members of the unit staff shall be specified by use of an overall qualification statement referencing an ANSI Standard acceptable to the NRC staff or by specifying individual position qualifications. Generally, the first method is preferable; however, the second method is adaptable to those unit staffs requiring special qualification statements because of unique organizational structures.

5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of

[Regulatory Guide 1.8, Revision 2, 1987, or more recent revisions, or ANSI Standard acceptable to the NRC staff]. [The staff not covered by Regulatory Guide 1.8 shall meet or exceed the minimum qualifications of Regulations, Regulatory Guides, or ANSI Standards acceptable to NRC staff].

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 Specification 5.3.1, perform the functions described in 10 CFR 50.54(m).

General Electric BWR/6 STS 5.3-1 Rev. 5.0

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 to 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.

General Electric BWR/6 STS 5.4-1 Rev. 5.0

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 [5.6.1] and Specification [5.6.2].

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 approval of the plant manager, and

c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of, or concurrent with, the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

General Electric BWR/6 STS 5.5-1 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include

[the Low Pressure Core Spray, High Pressure Core Spray, Residual Heat Removal, Reactor Core Isolation Cooling, hydrogen recombiner, process sampling, and Standby Gas Treatment]. The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements and

b. Integrated leak test requirements for each system at least once per

[18] months.

The provisions of SR 3.0.2 are applicable.

[ 5.5.3 Post Accident Sampling

---

REVIEWERS NOTE------------------------------------------

This program may be eliminated based on the implementation of NEDO-32991, Revision 0, "Regulatory Relaxation For BWR Post Accident Sampling Stations (PASS)," and the associated NRC Safety Evaluation dated June 12, 2001, and implementation of the following commitments:

1. [Licensee] has developed contingency plans for obtaining and analyzing highly radioactive samples from the reactor coolant system, suppression pool, and containment atmosphere. The contingency plans will be contained in emergency plan implementing procedures and implemented with the implementation of the License amendment. Establishment of contingency plans is considered a regulatory commitment.

2. The capability for classifying fuel damage events at the Alert level threshold has been established for [plant] at radioactivity levels of 300 mCi/cc dose equivalent iodine. This capability may use a normal sampling system or correlations of radiation readings to coolant concentrations. This capability will be described in emergency plan implementing procedures and implemented with the implementation of the License amendment. The capability for classifying fuel damage events is considered a regulatory commitment.

3. [Licensee] has established the capability to monitor radioactive iodines that have been released to offsite environs. This capability is described in our emergency plan implementing procedures. The capability to monitor radioactive iodines is considered a regulatory commitment.

This program provides controls that ensure the capability to obtain and analyze reactor coolant, radioactive gases, and particulates in plant gaseous effluents General Electric BWR/6 STS 5.5-2 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.3 Post Accident Sampling (continued) and containment atmosphere samples under accident conditions. The program shall include the following:

a. Training of personnel,

b. Procedures for sampling and analysis, and

c. Provisions for maintenance of sampling and analysis equipment. ]

5.5.4 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM,

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001-20.2402,

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM,

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I,

e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days.

Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least every 31 days,

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I, General Electric BWR/6 STS 5.5-3 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be in accordance with the following:

1. For noble gases: a dose rate 500 mrem/yr to the whole body and a dose rate 3000 mrem/yr to the skin and

2. For 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.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Section [ ], cyclic and transient occurrences to ensure that components are maintained within the design limits.

[ 5.5.6 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containments, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. The program shall include baseline measurements prior to initial operations. The Tendon Surveillance Program, inspection frequencies, and acceptance criteria shall be in accordance with Section XI, Subsection IWL of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR 50.55a, except where an alternative, exemption, or relief has been authorized by the NRC.

The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies. ]

General Electric BWR/6 STS 5.5-4 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in [Regulatory Guide ], and in accordance with [Regulatory Guide 1.52, Revision 2; ASME N510-1989; and AG-1].

a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < [0.05]% when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below

[+/- 10%]:

ESF Ventilation System Flowrate

[ ] [ ]

b. Demonstrate for each of the ESF systems 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 2, and ASME N510-1989] at the system flowrate specified below [+/- 10%]:

ESF Ventilation System Flowrate

[ ] [ ]

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in [Regulatory Guide 1.52, Revision 2], shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30C (86F) and the relative humidity specified below:

ESF Ventilation System Penetration RH Face Velocity (fps)

[ ] [See Reviewer's [See [See Reviewer's Note] Reviewer's Note]

Note]

---

REVIEWER'S NOTE----------------------------------------

The use of any standard other than ASTM D3803-1989 to test the charcoal sample may result in an overestimation of the capability of the charcoal to adsorb radioiodine. As a result, the ability of the charcoal filters to perform in a manner consistent with the licensing basis for the facility is indeterminate.

ASTM D 3803-1989 is a more stringent testing standard because it does not differentiate between used and new charcoal, it has a longer equilibration period performed at a temperature of 30C (86F) and a relative humidity (RH) of 95%

General Electric BWR/6 STS 5.5-5 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (continued)

(or 70% RH with humidity control), and it has more stringent tolerances that improve repeatability of the test.

Allowable Penetration = [(100% - Methyl Iodide Efficiently

• for Charcoal Credited in Licensee's Accident Analysis) / Safety Factor]

When ASTM D3803-1989 is used with 30C (86F) and 95% RH (or 70% RH with humidity control) is used, the staff will accept the following:

Safety factor 2 for systems with or without humidity control.

Humidity control can be provided by heaters or an NRC-approved analysis that demonstrates that the air entering the charcoal will be maintained less than or equal to 70 percent RH under worst-case design basis conditions.

If the system has a face velocity greater than 110 percent of 0.203 m/s (40 ft/min), the face velocity should be specified.

• This value should be the efficiency that was incorporated in the licensee's accident analysis which was reviewed and approved by the staff in a safety evaluation.

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below [+/- 10%]:

ESF Ventilation System Delta P Flowrate

[ ] [ ] [ ]

[ e. Demonstrate that the heaters for each of the ESF systems dissipate the value specified below [+/- 10%] when tested in accordance with

[ASME N510-1989]:

ESF Ventilation System Wattage ]

[ ] [ ]

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

General Electric BWR/6 STS 5.5-6 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the [Waste Gas Holdup System], [the quantity of radioactivity contained in gas storage tanks or fed into the offgas treatment system, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks]. The gaseous radioactivity quantities shall be determined following the methodology in [Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure"]. The liquid radwaste quantities shall be determined in accordance with [Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures"].

The program shall include:

a. The limits for concentrations of hydrogen and oxygen in the [Waste Gas Holdup System] and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion),

b. A surveillance program to ensure that the quantity of radioactivity contained in [each gas storage tank and fed into the offgas treatment system] is less than the amount that would result in a whole body exposure of 0.5 rem to any individual in an unrestricted area, in the event of [an uncontrolled release of the tanks' contents], and

c. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the [Liquid Radwaste Treatment System] is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

5.5.9 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

General Electric BWR/6 STS 5.5-7 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Program (continued)

1. An API gravity or an absolute specific gravity within limits,

2. A flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3. A clear and bright appearance with proper color or a water and sediment content within limits,

b. Within 31 days following addition of the new fuel oil to storage tanks, verify that the properties of the new fuel oil, other than those addressed in a.,

above, are within limits for ASTM 2D fuel oil, and

c. Total particulate concentration of the fuel oil is 10 mg/l when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program testing frequencies.

5.5.10 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.

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 5.5.10b 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).

General Electric BWR/6 STS 5.5-8 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected,

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists,

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities, and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power, or no concurrent loss of onsite diesel generator(s), 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 system(s) supported by the inoperable support system is also inoperable,

b. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable, or

c. A required system redundant to 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.

General Electric BWR/6 STS 5.5-9 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program

[OPTION A]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option A, as modified by approved exemptions.

b. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]%

of containment air weight per day.

c. 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 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].

d. The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.

e. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

[OPTION B]

a. A program shall establish 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 the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

General Electric BWR/6 STS 5.5-10 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program (continued)

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

[ 3. ...]

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is [45 psig]. The containment design pressure is

[50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]%

of containment air weight per day.

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 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 Primary 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.

[OPTION A/B Combined]

a. A program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J. [Type A][Type B and C] test requirements are in accordance with 10 CFR 50, Appendix J, Option A, as modified by approved exemptions. [Type B and C][Type A]

test requirements are in accordance with 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. The 10 CFR 50, Appendix J, General Electric BWR/6 STS 5.5-11 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program (continued)

Option B test requirements 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 the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

[ 3. ...]

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is [45 psig]. The containment design pressure is

[50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]%

of containment air weight per day.

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 C tests and [< 0.75 La for Option A Type A tests] [ 0.75 La for Option B 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 Primary Containment Leakage Rate Testing Program.

General Electric BWR/6 STS 5.5-12 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program (continued)

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

5.5.13 Battery Monitoring and Maintenance Program

---

REVIEWERS NOTE------------------------------------------

This program and the corresponding requirements in LCO 3.8.4, LCO 3.8.5, and LCO 3.8.6 require providing the information and verifications requested in the Notice of Availability for TSTF-500, Revision 2, "DC Electrical Rewrite - Update to TSTF-360," (76FR54510).

This Program provides controls for battery restoration and maintenance. The program shall be in accordance with IEEE Standard (Std) 450-2002, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," as endorsed by Regulatory Guide 1.129, Revision 2 (RG), with RG exceptions and program provisions as identified below:

a. The program allows the following RG 1.129, Revision 2 exceptions:

1. Battery temperature correction may be performed before or after conducting discharge tests.

2. RG 1.129, Regulatory Position 1, Subsection 2, "References," is not applicable to this program.

3. In lieu of RG 1.129, Regulatory Position 2, Subsection 5.2, "Inspections," the following shall be used: "Where reference is made to the pilot cell, pilot cell selection shall be based on the lowest voltage cell in the battery."

4 In Regulatory Guide 1.129, Regulatory Position 3, Subsection 5.4.1, "State of Charge Indicator," the following statements in paragraph (d) may be omitted: "When it has been recorded that the charging current has stabilized at the charging voltage for three consecutive hourly measurements, the battery is near full charge. These measurements shall be made after the initially high charging current decreases sharply and the battery voltage rises to approach the charger output voltage."

5. In lieu of RG 1.129, Regulatory Position 7, Subsection 7.6, "Restoration," the following may be used: "Following the test, record the float voltage of each cell of the string."

b. The program shall include the following provisions:

General Electric BWR/6 STS 5.5-13 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Battery Monitoring and Maintenance Program (continued)

1. Actions to restore battery cells with float voltage < [2.13] V;

2. Actions to determine whether the float voltage of the remaining battery cells is [2.13] V when the float voltage of a battery cell has been found to be < [2.13] V;

3. Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the plates;

4. Limits on average electrolyte temperature, battery connection resistance, and battery terminal voltage; and

5. A requirement to obtain specific gravity readings of all cells at each discharge test, consistent with manufacturer recommendations.

5.5.14 Control Room Envelope (CRE) Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE [Main Control Room Environmental Control (MCREC)] System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of [5 rem whole body or its equivalent to any part of the body] [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 CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.

[The following are exceptions to Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0:

1. ;and]

General Electric BWR/6 STS 5.5-14 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Control Room Envelope (CRE) Habitability Program (continued)

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one subsystem of the [MCREC] System, operating at the flow rate required by the VFTP, at a Frequency of [18] months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the [18] month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

[ 5.5.15 Setpoint Control Program

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REVIEWER'S NOTE----------------------------------------

Adoption of a Setpoint Control Program requires changes to other technical specifications. See TSTF-493, Revision 4, "Clarify Application of Setpoint Methodology for LSSS Functions," Option B, for guidance (Agencywide Documents Access and Management System (ADAMS) Accession Number ML101160026).

This program shall establish the requirements for ensuring that setpoints for automatic protective devices are initially within and remain within the assumptions of the applicable safety analyses, provides a means for processing changes to instrumentation setpoints, and identifies setpoint methodologies to ensure instrumentation will function as required. The program shall ensure that testing of automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1)(ii)(A) verifies that instrumentation will function as required.

a. The program shall list the Functions in the following specifications to which it applies:

1. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation;"

2. LCO 3.3.1.2, "Source Range Monitor (SRM) Instrumentation;"

General Electric BWR/6 STS 5.5-15 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Setpoint Control Program (continued)

3. LCO 3.3.2.1, "Control Rod Block Instrumentation;"

4. LCO 3.3.2.2, "Feedwater and Main Turbine High Water Level Trip Instrumentation;"

5. LCO 3.3.4.1, "End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation;"

6. LCO 3.3.4.2, "Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation;"

7. LCO 3.3.5.1, "Emergency Core Cooling System (ECCS)

Instrumentation;"

8. LCO 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation,"

9. LCO 3.3.5.3, "Reactor Core Isolation Cooling (RCIC) System Instrumentation;"

10. LCO 3.3.6.1, "Primary Containment Isolation Instrumentation;"

11. LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation;"

12. LCO 3.3.6.3, "Low-Low Set (LLS) Instrumentation;"

13. LCO 3.3.7.1, "[Main Control Room Environmental Control (MCREC)]

System Instrumentation;"

14. LCO 3.3.8.1, "Loss of Power (LOP) Instrumentation;"

15. LCO 3.3.8.2, "Reactor Protection System (RPS) Electric Power Monitoring."

b. The program shall require the [Limiting Trip Setpoint (LTSP)], [Nominal Trip Setpoint NTSP], Allowable Value (AV), As-Found Tolerance (AFT), and As-Left Tolerance (ALT) (as applicable) of the Functions described in paragraph a. are calculated using the NRC approved setpoint methodology, as listed below. In addition, the program shall contain the value of the

[LTSP], [NTSP], AV, AFT, and ALT (as applicable) for each Function described in paragraph a. and shall identify the setpoint methodology used to calculate these values.

---

Reviewer's Note ---------------------------------------

List the NRC safety evaluation report by letter, date, and ADAMS accession number (if available) that approved the setpoint methodologies.

1. [Insert reference to NRC safety evaluation that approved the setpoint methodology.]

c. The program shall establish methods to ensure that Functions described in paragraph a. will function as required by verifying the as-left and as-found settings are consistent with those established by the setpoint methodology.

General Electric BWR/6 STS 5.5-16 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Setpoint Control Program (continued)

d. ---------------------------------- REVIEWERS NOTE -------------------------------------

A license amendment request to implement a Setpoint Control Program must list the instrument functions to which the program requirements of paragraph d. will be applied. Paragraph d. shall apply to all Functions in the Reactor Protection System (RPS) Instrumentation, Control Rod Block Instrumentation, End of Cycle-Recirculation Pump Trip (EOC-RPT)

Instrumentation, Emergency Core Cooling System (ECCS) Instrumentation, and Reactor Core Isolation Cooling (RCIC) Instrumentation specifications unless one or more of the following exclusions apply:

1. Manual actuation circuits, automatic actuation logic circuits or to instrument functions that derive input from contacts which have no associated sensor or adjustable device, e.g., limit switches, breaker position switches, manual actuation switches, float switches, proximity detectors, etc. are excluded. In addition, those permissives and interlocks that derive input from a sensor or adjustable device that is tested as part of another TS function are excluded.

2. Settings associated with safety relief valves are excluded. The performance of these components is already controlled (i.e., trended with as-left and as-found limits) under the ASME Code for Operation and Maintenance of Nuclear Power Plants testing program.

3. Functions and Surveillance Requirements which test only digital components are normally excluded. There is no expected change in result between SR performances for these components. Where separate as-left and as-found tolerance is established for digital component SRs, the requirements would apply.

The program shall identify the Functions described in paragraph a. that are automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1)(ii)(A). The [LTSP] of these Functions are Limiting Safety System Settings. These Functions shall be demonstrated to be functioning as required by applying the following requirements during CHANNEL CALIBRATIONS, trip unit calibrations and CHANNEL FUNCTIONAL TESTS that verify the [LTSP or NTSP].

1 The as-found value of the instrument channel trip setting shall be compared with the previous as-left value or the specified [LTSP or NTSP].

2. If the as-found value of the instrument channel trip setting differs from the previous as-left value or the specified [LTSP or NTSP] by more than the pre-defined test acceptance criteria band (i.e., the specified General Electric BWR/6 STS 5.5-17 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Setpoint Control Program (continued)

AFT), then the instrument channel shall be evaluated before declaring the SR met and returning the instrument channel to service. This condition shall be entered in the plant corrective action program.

3. If the as-found value of the instrument channel trip setting is less conservative than the specified AV, then the SR is not met and the instrument channel shall be immediately declared inoperable.

4. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the [LTSP or NTSP] at the completion of the surveillance test; otherwise, the channel is inoperable (setpoints may be more conservative than the [LTSP or NTSP] provided that the as-found and as-left tolerances apply to the actual setpoint used to confirm channel performance).

e. The program shall be specified in [insert the facility FSAR reference or the name of any document incorporated into the facility FSAR by reference]. ]

[ 5.5.16 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

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

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

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

[ 5.5.17 Risk Informed Completion Time Program This program provides controls to calculate a Risk Informed Completion Time (RICT) and must be implemented in accordance with NEI 06-09-A, Revision 0, "Risk-Managed Technical Specifications (RMTS) Guidelines." The program shall include the following:

a. The RICT may not exceed 30 days; General Electric BWR/6 STS 5.5-18 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.17 Risk Informed Completion Time Program (continued)

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REVIEWER'S NOTE ----------------------------------

The Risk Informed Completion Time is only applicable in MODES supported by the licensee's PRA. Licensees applying the RICT Program to MODES other than MODES 1 and 2 must demonstrate that they have the capability to calculate a RICT in those MODES or that the risk indicated by their MODE 1 and 2 PRA model is bounding with respect to the lower MODE conditions.

b. A RICT may only be utilized in MODE 1, 2 [, and 3, and MODE 4 while relying on steam generators for heat removal];

c. When a RICT is being used, any change to the plant configuration, as defined in NEI 06-09-A, Appendix A, must be considered for the effect on the RICT.

1. For planned changes, the revised RICT must be determined prior to implementation of the change in configuration.

2. For emergent conditions, the revised RICT must be determined within the time limits of the Required Action Completion Time (i.e., not the RICT) or 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after the plant configuration change, whichever is less.

3. Revising the RICT is not required if the plant configuration change would lower plant risk and would result in a longer RICT.

d. For emergent conditions, if the extent of condition evaluation for inoperable structures, systems, or components (SSCs) is not complete prior to exceeding the Completion Time, the RICT shall account for the increased possibility of common cause failure (CCF) by either:

1. Numerically accounting for the increased possibility of CCF in the RICT calculation; or

2. Risk Management Actions (RMAs) not already credited in the RICT calculation shall be implemented that support redundant or diverse SSCs that perform the function(s) of the inoperable SSCs, and, if practicable, reduce the frequency of initiating events that challenge the function(s) performed by the inoperable SSCs.

General Electric BWR/6 STS 5.5-19 Rev. 5.0

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.17 Risk Informed Completion Time Program (continued)

e. The risk assessment approaches and methods shall be acceptable to the NRC. The plant PRA shall be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant, as specified in Regulatory Guide 1.200, Revision 2. Methods to assess the risk from extending the Completion Times must be PRA methods used to support this license amendment, or other methods approved by the NRC for generic use; and any change in the PRA methods to assess risk that are outside these approval boundaries require prior NRC approval. ]

[ 5.5.18 Spent Fuel Storage Rack Neutron Absorber Monitoring Program This Program provides controls for monitoring the condition of the neutron absorber used in the spent fuel pool storage racks to verify the Boron-10 areal density is consistent with the assumptions in the spent fuel pool criticality analysis. The program shall be in accordance with NEI 16-03-A, "Guidance for Monitoring of Fixed Neutron Absorbers in Spent Fuel Pools," Revision 0, May 2017 [, with the following exceptions:

1. . . . ].]

General Electric BWR/6 STS 5.5-20 Rev. 5.0

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 Annual Radiological Environmental Operating Report

---

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

[ A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station. ]

The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements [in the format of the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979]. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

5.6.2 Radioactive Effluent Release Report

---

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

[ A single submittal may be made for a multiple unit station. The submittal shall combine sections common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit. ]

The Radioactive Effluent Release Report covering the operation of the unit during the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.

General Electric BWR/6 STS 5.6-1 Rev. 5.0

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.3 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:

[ The individual specifications that address core operating limits must be referenced here. The MCPR99.9% value used to calculate the LCO 3.2.2, "MCPR," limit shall be specified in the COLR. ]

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:

---

REVIEWERS NOTE----------------------------------------

Licensees that have received prior NRC approval to relocate Topical Report revision numbers and dates to licensee control need only list the number and title of the Topical Report, and the COLR will contain the complete identification for each of the Technical Specification referenced Topical Reports used to prepare the COLR (i.e., report number, title, revision, date, and any supplements). See NRC ADAMS Accession No: ML110660285 for details.

[ Identify the Topical Report(s) by number, title, date, and NRC staff approval document or identify the staff Safety Evaluation Report for a plant specific methodology by NRC letter and date. ]

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

5.6.4 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT

a. RCS pressure and temperature limits for heatup, cooldown, low temperature operation, criticality, and hydrostatic testing as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

[ The individual specifications that address RCS pressure and temperature limits must be referenced here. ]

General Electric BWR/6 STS 5.6-2 Rev. 5.0

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 RCS PRESSURE AND TEMPERATURE LIMITS REPORT (continued)

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 documents:

---

REVIEWERS NOTE----------------------------------------

Licensees that have received prior NRC approval to relocate Topical Report revision numbers and dates to licensee control need only list the number and title of the Topical Report, and the PTLR will contain the complete identification for each of the Technical Specification referenced Topical Reports used to prepare the PTLR (i.e., report number, title, revision, date, and any supplements). See NRC ADAMS Accession No: ML110660285 for details.

[ Identify the NRC staff approval document by date. ]

c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

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REVIEWER'S NOTE----------------------------------------

The methodology for the calculation of the P-T limits for NRC approval should include the following provisions:

1. The methodology shall describe how the neutron fluence is calculated (reference new Regulatory Guide when issued).

2. The Reactor Vessel Material Surveillance Program shall comply with Appendix H to 10 CFR 50. The reactor vessel material irradiation surveillance specimen removal schedule shall be provided, along with how the specimen examinations shall be used to update the PTLR curves.

3. Low Temperature Overpressure Protection (LTOP) System lift setting limits for the Power Operated Relief Valves (PORVs), developed using NRC-approved methodologies may be included in the PTLR.

4. The adjusted reference temperature (ART) for each reactor beltline material shall be calculated, accounting for radiation embrittlement, in accordance with Regulatory Guide 1.99, Revision 2.

5. The limiting ART shall be incorporated into the calculation of the pressure and temperature limit curves in accordance with NUREG-0800 Standard Review Plan 5.3.2, Pressure-Temperature Limits.

General Electric BWR/6 STS 5.6-3 Rev. 5.0

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 RCS PRESSURE AND TEMPERATURE LIMITS REPORT (continued)

6. The minimum temperature requirements of Appendix G to 10 CFR Part 50 shall be incorporated into the pressure and temperature limit curves.

7. Licensees who have removed two or more capsules should compare for each surveillance material the measured increase in reference temperature (RTNDT) to the predicted increase in RTNDT; where the predicted increase in RTNDT is based on the mean shift in RTNDT plus the two standard deviation value (2) specified in Regulatory Guide 1.99, Revision 2. If the measured value exceeds the predicted value (increase in RTNDT + 2), the licensee should provide a supplement to the PTLR to demonstrate how the results affect the approved methodology.

5.6.5 Post Accident Monitoring Report When a Special Report is required by Condition B or F of LCO 3.3.[3.1], "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.

5.6.6 [ Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

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REVIEWER'S NOTE----------------------------------------

These reports may be required covering inspection, test, and maintenance activities. These reports are determined on an individual basis for each unit and their preparation and submittal are designated in the Technical Specifications.

General Electric BWR/6 STS 5.6-4 Rev. 5.0

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 device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or

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 General Electric BWR/6 STS 5.7-1 Rev. 5.0

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)

(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 that 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 designee.

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

b. Access to, and activities in, each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

General Electric BWR/6 STS 5.7-2 Rev. 5.0

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 that 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

d. Each individual or group entering such an area shall possess one of the following:

1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance, as specified in the RWP or equivalent, while in the area, by means of closed circuit television, 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.

4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

General Electric BWR/6 STS 5.7-3 Rev. 5.0

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 that 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

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.

General Electric BWR/6 STS 5.7-4 Rev. 5.0

NRC FORM 335 U.S. NUCLEAR REGULATORY COMMISSION 1. REPORT NUMBER (12-2010) (Assigned by NRC, Add Vol., Supp., Rev.,

NRCMD 3.7 and Addendum Numbers, if any.)

BIBLIOGRAPHIC DATA SHEET NUREG-1434, Volume 1, (See instructions on the reverse) Revision 5.0

2. TITLE AND SUBTITLE 3. DATE REPORT PUBLISHED Standard Technical Specifications, General Electric Plants, BWR/6: Specifications (Revision 5) MONTH YEAR September 2021

4. FIN OR GRANT NUMBER

5. AUTHOR(S) 6. TYPE OF REPORT Multiple Technical

7. PERIOD COVERED (Inclusive Dates)

8. PERFORMING ORGANIZATION - NAME AND ADDRESS (If NRC, provide Division, Office or Region, U. S. Nuclear Regulatory Commission, and mailing address; if contractor, provide name and mailing address.)

Division of Safety Systems Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

9. SPONSORING ORGANIZATION - NAME AND ADDRESS (If NRC, type "Same as above", if contractor, provide NRC Division, Office or Region, U. S. Nuclear Regulatory Commission, and mailing address.)

Save as above

10. SUPPLEMENTARY NOTES

11. ABSTRACT (200 words or less)

This NUREG contains the improved Standard Technical Specifications (STS) for General Electric, BWR/6 plants. The changes reflected in Revision 5 result from the experience gained from plant operation using the improved STS and extensive public technical meetings and discussions among the Nuclear Regulatory Commission (NRC) staff and various nuclear power plant licensees and the Nuclear Steam Supply System (NSSS) Owners Groups.

The improved STS were developed based on the criteria in the Final Commission Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors, dated July 22, 1993 (58 FR 39132), which was subsequently codified by changes to Section 36 of Part 50 of Title 10 of the Code of Federal Regulations (10 CFR 50.36) (60 FR 36953). Licensees are encouraged to upgrade their technical specifications consistent with those criteria and conforming, to the practical extent, to Revision 5 to the improved STS. The Commission continues to place the highest priority on requests for complete conversions to the improved STS. Licensees adopting portions of the improved STS to existing technical specifications should adopt all related requirements, as applicable, to achieve a high degree of standardization and consistency.

Users may access the STS NUREGs in the PDF format at (http://www.nrc.gov). Users may print or download copies from the NRC Web site.

12. KEY WORDS/DESCRIPTORS (List words or phrases that will assist researchers in locating the report.) 13. AVAILABILITY STATEMENT NUREG-1434 unlimited Standard Technical Specifications 14. SECURITY CLASSIFICATION STS (This Page)

General Electric unclassified GE (This Report) unclassified

15. NUMBER OF PAGES

16. PRICE NRC FORM 335 (12-2010)

NUREG-1434, Volume 1 Standard Technical Specifications September 2021 Revision 5 General Electric BWR/6 Plants: Specifications