Standard Technical 

Specifications

General Electric BWR/6 

Plants

Revision 4.0

Volume 1, Specifications

Office of Nuclear Reactor Regulation

NUREG-1434

Volume 1

Revision 4.0

Standard Technical 

Specifications

General Electric BWR/6

Plants

Revision 4.0

Volume 1, Specifications

Manuscript Completed: October 2011

Date Published: April 2012

Office of Nuclear Reactor Regulation

NUREG-1434

Volume 1

Revision 4.0
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General Electric BWR/6 STS iii Rev. 4.0

ABSTRACT

This NUREG contains the improved Standard Technical Specifications (STS) for General 

Electric Boiling Water Reactor/6 (BWR/6) plants. The changes reflected in Revision 4 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 4 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.

PAPERWORK REDUCTION ACT STATEMENT

The information collections contained in this NUREG are covered by the requirements of 

10 CFR Part 50, which were approved by the Office of Management and Budget, approval 

number 3150-0011.

PUBLIC PROTECTION NOTIFICATION

If a means used to impose an information collection does not display a currently valid OMB 

control number, the NRC may not conduct or sponsor, and a person is not required to respond 

to, the information collection.

General Electric BWR/6 STS v Rev. 4.0

TABLE OF CONTENTS / REVISION SUMMARY Page Rev.

1.0 USE AND APPLICATION

1.1 Definitions.....................................................................................................1.1-1 4.0

1.2 Logical Connectors.......................................................................................1.2-1 4.0

1.3 Completion Times ........................................................................................1.3-1 4.0

1.4 Frequency ....................................................................................................1.4-1 4.0

2.0 SAFETY LIMITS (SLs).......................................................................................2.0-1 4.0

2.1 Safety Limits

2.2 SL Violations

3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY..................3.0-1 4.0

3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY.................................3.0-4 4.0

3.1 REACTIVITY CONTROL SYSTEMS

3.1.1 SHUTDOWN MARGIN (SDM) ..................................................................3.1.1-1 4.0

3.1.2 Reactivity Anomalies .................................................................................3.1.2-1 4.0

3.1.3 Control Rod OPERABILITY.......................................................................3.1.3-1 4.0

3.1.4 Control Rod Scram Times .........................................................................3.1.4-1 4.0

3.1.5 Control Rod Scram Accumulators .............................................................3.1.5-1 4.0

3.1.6 Rod Pattern Control...................................................................................3.1.6-1 4.0

3.1.7 Standby Liquid Control (SLC) System.......................................................3.1.7-1 4.0

3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ..........................3.1.8-1 4.0

3.2 POWER DISTRIBUTION LIMITS

3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE

(APLHGR) ...........................................................................................3.2.1-1 4.0

3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) ........................................3.2.2-1 4.0

3.2.3 LINEAR HEAT GENERATION RATE (LHGR) (Optional) .........................3.2.3-1 4.0

3.2.4 Average Power Range Monitor (APRM) Gain and Setpoints 

(Optional).............................................................................................3.2.4-1 4.0

3.3 INSTRUMENTATION

(Section 3.3 Specifications with an "A" suffix include setpoints. Specifications with a "B" suffix 

reflect a Setpoint Control Program.)

3.3.1.1A Reactor Protection System (RPS) Instrumentation ..............................3.3.1.1A-1 4.0

3.3.1.1B Reactor Protection System (RPS) Instrumentation ..............................3.3.1.1B-1 4.0

3.3.1.2A Source Range Monitor (SRM) Instrumentation ....................................3.3.1.2A-1 4.0

3.3.1.2B Source Range Monitor (SRM) Instrumentation ....................................3.3.1.2B-1 4.0

3.3.2.1A Control Rod Block Instrumentation.......................................................3.3.2.1A-1 4.0

3.3.2.1B Control Rod Block Instrumentation.......................................................3.3.2.1B-1 4.0

3.3.3.1 Post Accident Monitoring (PAM) Instrumentation...................................3.3.3.1-1 4.0

3.3.3.2 Remote Shutdown System.....................................................................3.3.3.2-1 4.0

3.3.4.1A End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ....3.3.4.1A-1 4.0

3.3.4.1B End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ....3.3.4.1B-1 4.0

3.3.4.2A Anticipated Transient Without Scram Recirculation Pump Trip 

(ATWS-RPT) Instrumentation.........................................................3.3.4.2A-1 4.0

3.3.4.2B Anticipated Transient Without Scram Recirculation Pump Trip 

(ATWS-RPT) Instrumentation.........................................................3.3.4.2B-1 4.0
General Electric BWR/6 STS vi Rev. 4.0

TABLE OF CONTENTS / REVISION SUMMARY Page Rev.

3.3 INSTRUMENTATION (continued)

3.3.5.1A Emergency Core Cooling System (ECCS) Instrumentation .................3.3.5.1A-1 4.0

3.3.5.1B Emergency Core Cooling System (ECCS) Instrumentation .................3.3.5.1B-1 4.0

3.3.5.2A Reactor Core Isolation Cooling (RCIC) System Instrumentation .........3.3.5.2A-1 4.0

3.3.5.2B Reactor Core Isolation Cooling (RCIC) System Instrumentation .........3.3.5.2B-1 4.0

3.3.6.1A Primary Containment Isolation Instrumentation ...................................3.3.6.1A-1 4.0

3.3.6.1B Primary Containment Isolation Instrumentation ...................................3.3.6.1B-1 4.0

3.3.6.2A Secondary Containment Isolation Instrumentation...............................3.3.6.2A-1 4.0

3.3.6.2B Secondary Containment Isolation Instrumentation...............................3.3.6.2B-1 4.0

3.3.6.3A Residual Heat Removal (RHR) Containment Spray System 

Instrumentation...............................................................................3.3.6.3A-1 4.0

3.3.6.3B Residual Heat Removal (RHR) Containment Spray System 

Instrumentation...............................................................................3.3.6.3B-1 4.0

3.3.6.4A Suppression Pool Makeup (SPMU) System Instrumentation...............3.3.6.4A-1 4.0

3.3.6.4B Suppression Pool Makeup (SPMU) System Instrumentation...............3.3.6.4B-1 4.0

3.3.6.5A Relief and Low-Low Set (LLS) Instrumentation....................................3.3.6.5A-1 4.0

3.3.6.5B Relief and Low-Low Set (LLS) Instrumentation....................................3.3.6.5B-1 4.0

3.3.7.1A [Control Room Fresh Air (CRFA)] System Instrumentation..................3.3.7.1A-1 4.0

3.3.7.1B [Control Room Fresh Air (CRFA)] System Instrumentation..................3.3.7.1B-1 4.0

3.3.8.1A Loss of Power (LOP) Instrumentation ..................................................3.3.8.1A-1 4.0

3.3.8.1B Loss of Power (LOP) Instrumentation ..................................................3.3.8.1B-1 4.0

3.3.8.2A Reactor Protection System (RPS) Electric Power Monitoring ..............3.3.8.2A-1 4.0

3.3.8.2B Reactor Protection System (RPS) Electric Power Monitoring ..............3.3.8.2B-1 4.0

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.1 Recirculation Loops Operating..................................................................3.4.1-1 4.0

3.4.2 Flow Control Valves (FCVs)......................................................................3.4.2-1 4.0

3.4.3 Jet Pumps .................................................................................................3.4.3-1 4.0

3.4.4 Safety/Relief Valves (S/RVs).....................................................................3.4.4-1 4.0

3.4.5 RCS Operational LEAKAGE .....................................................................3.4.5-1 4.0

3.4.6 RCS Pressure Isolation Valve (PIV) Leakage ...........................................3.4.6-1 4.0

3.4.7 RCS Leakage Detection Instrumentation ..................................................3.4.7-1 4.0

3.4.8 RCS Specific Activity.................................................................................3.4.8-1 4.0

3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot 

Shutdown ............................................................................................3.4.9-1 4.0

3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold 

Shutdown ..........................................................................................3.4.10-1 4.0

3.4.11 RCS Pressure and Temperature (P/T) Limits .........................................3.4.11-1 4.0

3.4.12 Reactor Steam Dome Pressure ..............................................................3.4.12-1 4.0

3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR 

CORE ISOLATION COOLING (RCIC) SYSTEM

3.5.1 ECCS - Operating .....................................................................................3.5.1-1 4.0

3.5.2 ECCS - Shutdown .....................................................................................3.5.2-1 4.0

3.5.3 RCIC System.............................................................................................3.5.3-1 4.0

3.6 CONTAINMENT SYSTEMS

3.6.1.1 Primary Containment..............................................................................3.6.1.1-1 4.0

3.6.1.2 Primary Containment Air Locks..............................................................3.6.1.2-1 4.0

3.6.1.3 Primary Containment Isolation Valves (PCIVs)......................................3.6.1.3-1 4.0
General Electric BWR/6 STS vii Rev. 4.0

TABLE OF CONTENTS / REVISION SUMMARY Page Rev.

3.6 CONTAINMENT SYSTEMS (continued)

3.6.1.4 Primary Containment Pressure ..............................................................3.6.1.4-1 4.0

3.6.1.5 Primary Containment Air Temperature...................................................3.6.1.5-1 4.0

3.6.1.6 Low-Low Set (LLS) Valves .....................................................................3.6.1.6-1 4.0

3.6.1.7 Residual Heat Removal (RHR) Containment Spray System..................3.6.1.7-1 4.0

3.6.1.8 Penetration Valve Leakage Control System (PVLCS) ...........................3.6.1.8-1 4.0

3.6.1.9 Main Steam Isolation Valve (MSIV) Leakage Control System (LCS).....3.6.1.9-1 4.0

3.6.2.1 Suppression Pool Average Temperature ...............................................3.6.2.1-1 4.0

3.6.2.2 Suppression Pool Water Level ...............................................................3.6.2.2-1 4.0

3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ....................3.6.2.3-1 4.0

3.6.2.4 Suppression Pool Makeup (SPMU) System...........................................3.6.2.4-1 4.0

3.6.3.1 Primary Containment and Drywell Hydrogen Ignitors ...........................3.6.3.1-1 4.0

3.6.3.2 [ Drywell Purge System .........................................................................3.6.3.2-1 4.0 ]

3.6.4.1 [ Secondary Containment.......................................................................3.6.4.1-1 4.0 ]

3.6.4.2 Secondary Containment Isolation Valves (SCIVs).................................3.6.4.2-1 4.0

3.6.4.3 Standby Gas Treatment (SGT) System .................................................3.6.4.3-1 4.0

3.6.5.1 Drywell....................................................................................................3.6.5.1-1 4.0

3.6.5.2 Drywell Air Lock......................................................................................3.6.5.2-1 4.0

3.6.5.3 Drywell Isolation Valves ........................................................................3.6.5.3-1 4.0

3.6.5.4 Drywell Pressure ....................................................................................3.6.5.4-1 4.0

3.6.5.5 Drywell Air Temperature.........................................................................3.6.5.5-1 4.0

3.6.5.6 Drywell Vacuum Relief System ..............................................................3.6.5.6-1 4.0

3.7 PLANT SYSTEMS

3.7.1 [Standby Service Water (SSW)] System and [Ultimate Heat Sink 

(UHS)] .................................................................................................3.7.1-1 4.0

3.7.2 High Pressure Core Spray (HPCS) Service Water System (SWS)...........3.7.2-1 4.0

3.7.3 [Control Room Fresh Air (CRFA)] System ................................................3.7.3-1 4.0

3.7.4 [Control Room Air Conditioning (AC)] System ..........................................3.7.4-1 4.0

3.7.5 Main Condenser Offgas ............................................................................3.7.5-1 4.0

3.7.6 Main Turbine Bypass System....................................................................3.7.6-1 4.0

3.7.7 Fuel Pool Water Level...............................................................................3.7.7-1 4.0

3.8 ELECTRICAL POWER SYSTEMS

3.8.1 AC Sources - Operating ............................................................................3.8.1-1 4.0

3.8.2 AC Sources - Shutdown............................................................................3.8.2-1 4.0

3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air.................................................3.8.3-1 4.0

3.8.4 DC Sources - Operating............................................................................3.8.4-1 4.0

3.8.5 DC Sources - Shutdown............................................................................3.8.5-1 4.0

3.8.6 Battery Parameters ...................................................................................3.8.6-1 4.0

3.8.7 Inverters - Operating .................................................................................3.8.7-1 4.0

3.8.8 Inverters - Shutdown .................................................................................3.8.8-1 4.0

3.8.9 Distribution Systems - Operating...............................................................3.8.9-1 4.0

3.8.10 Distribution Systems - Shutdown ............................................................3.8.10-1 4.0
General Electric BWR/6 STS viii Rev. 4.0

TABLE OF CONTENTS / REVISION SUMMARY Page Rev.

3.9 REFUELING OPERATIONS

3.9.1 Refueling Equipment Interlocks.................................................................3.9.1-1 4.0

3.9.2 Refuel Position One-Rod-Out Interlock .....................................................3.9.2-1 4.0

3.9.3 Control Rod Position .................................................................................3.9.3-1 4.0

3.9.4 Control Rod Position Indication.................................................................3.9.4-1 4.0

3.9.5 Control Rod OPERABILITY - Refueling ....................................................3.9.5-1 4.0

3.9.6 [Reactor Pressure Vessel (RPT)] Water Level[ - Irradiated Fuel] .............3.9.6-1 4.0

[ 3.9.7 [Reactor Pressure Vessel (RPT)] Water Level - New Fuel or 

Control Rods .......................................................................................3.9.7-1 4.0 ]

3.9.8 Residual Heat Removal (RHR) - High Water Level...................................3.9.8-1 4.0

3.9.9 Residual Heat Removal (RHR) - Low Water Level ...................................3.9.9-1 4.0

3.10 SPECIAL OPERATIONS

3.10.1 Inservice Leak and Hydrostatic Testing Operation..................................3.10.1-1 4.0

3.10.2 Reactor Mode Switch Interlock Testing...................................................3.10.2-1 4.0

3.10.3 Single Control Rod Withdrawal - Hot Shutdown......................................3.10.3-1 4.0

3.10.4 Single Control Rod Withdrawal - Cold Shutdown....................................3.10.4-1 4.0

3.10.5 Single Control Rod Drive (CRD) Removal - Refueling ............................3.10.5-1 4.0

3.10.6 Multiple Control Rod Withdrawal - Refueling...........................................3.10.6-1 4.0

3.10.7 Control Rod Testing - Operating .............................................................3.10.7-1 4.0

3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling ......................................3.10.8-1 4.0

3.10.9 Recirculation Loops - Testing..................................................................3.10.9-1 4.0

3.10.10 Training Startups ...................................................................................3.10.10-1 4.0

4.0 DESIGN FEATURES .........................................................................................4.0-1 4.0

4.1 Site Location 

4.2 Reactor Core

4.3 Fuel Storage

5.0 ADMINISTRATIVE CONTROLS

5.1 Responsibility ...............................................................................................5.1-1 4.0

5.2 Organization.................................................................................................5.2-1 4.0

5.3 Unit Staff Qualifications ................................................................................5.3-1 4.0

5.4 Procedures ...................................................................................................5.4-1 4.0

5.5 Programs and Manuals ................................................................................5.5-1 4.0

5.6 Reporting Requirements ..............................................................................5.6-1 4.0

5.7 High Radiation Area .....................................................................................5.7-1 4.0
Definitions

1.1

General Electric BWR/6 STS 1.1-1 Rev. 4.0

1.0 USE AND APPLICATION

1.1 Definitions

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

The defined terms of this section appear in capitalized type and are applicable throughout these 

Technical Specifications and Bases.

-------------------------------------------------------------------------------------------------------------------------------

Term Definition

ACTIONS ACTIONS shall be that part of a Specification that prescribes 

Required Actions to be taken under designated Conditions 

within specified Completion Times.

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.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by 

observation, of channel behavior during operation. This 

determination shall include, where possible, comparison of the 

channel indication and status to other indications or status 

derived from independent instrument channels measuring the 

same parameter.

CHANNEL 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.
Definitions

1.1

General Electric BWR/6 STS 1.1-2 Rev. 4.0

1.1 Definitions

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"].

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.
Definitions

1.1

General Electric BWR/6 STS 1.1-3 Rev. 4.0

1.1 Definitions

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].

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.

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 either not to interfere with the operation of 

leakage detection systems or not to be pressure 

boundary LEAKAGE,

b. Unidentified LEAKAGE

All LEAKAGE into the drywell that is not identified 

LEAKAGE,

c. Total LEAKAGE

Sum of the identified and unidentified LEAKAGE, and
Definitions

1.1

General Electric BWR/6 STS 1.1-4 Rev. 4.0

1.1 Definitions

LEAKAGE (continued)

d. Pressure Boundary LEAKAGE

LEAKAGE through a nonisolable fault in a Reactor 

Coolant System (RCS) component body, pipe wall, or 

vessel wall.

[ 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. ]

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).
Definitions

1.1

General Electric BWR/6 STS 1.1-5 Rev. 4.0

1.1 Definitions

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.

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 assuming that:

a. The reactor is xenon free,

b. The moderator temperature is 68F, 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.
Definitions

1.1

General Electric BWR/6 STS 1.1-6 Rev. 4.0

1.1 Definitions

[ 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.

[ 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. ]
Definitions

1.1

General Electric BWR/6 STS 1.1-7 Rev. 4.0

Table 1.1-1 (page 1 of 1)

MODES

MODE TITLE

REACTOR MODE

SWITCH POSITION

AVERAGE REACTOR

COOLANT 

TEMPERATURE

(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.

Logical Connectors

1.2

General Electric BWR/6 STS 1.2-1 Rev. 4.0

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.
Logical Connectors

1.2

General Electric BWR/6 STS 1.2-2 Rev. 4.0

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.
Logical Connectors

1.2

General Electric BWR/6 STS 1.2-3 Rev. 4.0

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.

Completion Times

1.3

General Electric BWR/6 STS 1.3-1 Rev. 4.0

1.0 USE AND APPLICATION

1.3 Completion Times

PURPOSE The purpose of this section is to establish the Completion Time 

convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements 

for ensuring safe operation of the unit. The ACTIONS associated with an 

LCO state Conditions that typically describe the ways in which the 

requirements of the LCO can fail to be met. Specified with each stated 

Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a 

Required Action. It is referenced to the time of discovery of a situation 

(e.g., inoperable equipment or variable not within limits) that requires 

entering an ACTIONS Condition unless otherwise specified, providing the 

unit is in a MODE or specified condition stated in the Applicability of the 

LCO. Required Actions must be completed prior to the expiration of the 

specified Completion Time. An ACTIONS Condition remains in effect and 

the Required Actions apply until the Condition no longer exists or the unit 

is not within the LCO Applicability.

If situations are discovered that require entry into more than one 

Condition at a time within a single LCO (multiple Conditions), the 

Required Actions for each Condition must be performed within the 

associated Completion Time. When in multiple Conditions, separate 

Completion Times are tracked for each Condition starting from the time of 

discovery of the situation that required entry into the Condition.

Once a Condition has been entered, subsequent 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.

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.
Completion Times

1.3

General Electric BWR/6 STS 1.3-2 Rev. 4.0

1.3 Completion Times

DESCRIPTION (continued)

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 hours 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 reentry 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.

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 hours," 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 

Action and 

associated 

Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

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.
Completion Times

1.3

General Electric BWR/6 STS 1.3-3 Rev. 4.0

1.3 Completion Times

EXAMPLES (continued)

The Required Actions of Condition B are to be in MODE 3 within 12 hours 

AND in MODE 4 within 36 hours. A total of 12 hours is allowed for 

reaching MODE 3 and a total of 36 hours (not 48 hours) is allowed for 

reaching MODE 4 from the time that Condition B was entered. If MODE 3 

is reached within 6 hours, the time allowed for reaching MODE 4 is the 

next 30 hours because the total time allowed for reaching MODE 4 is 

36 hours.

If Condition B is entered while in MODE 3, the time allowed for reaching 

MODE 4 is the next 36 hours.

EXAMPLE 1.3-2

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One pump 

inoperable.

A.1 Restore pump to 

OPERABLE status.

7 days

B. Required 

Action and 

associated 

Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

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.
Completion Times

1.3

General Electric BWR/6 STS 1.3-4 Rev. 4.0

1.3 Completion Times

EXAMPLES (continued)

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.

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 hour extension to the stated 7 days is allowed, provided this does not 

result in the second pump being inoperable for > 7 days.
Completion Times

1.3

General Electric BWR/6 STS 1.3-5 Rev. 4.0

1.3 Completion Times

EXAMPLES (continued)

EXAMPLE 1.3-3

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One 

Function X 

subsystem 

inoperable.

A.1 Restore Function X 

subsystem to 

OPERABLE status.

7 days

B. One 

Function Y 

subsystem 

inoperable.

B.1 Restore Function Y 

subsystem to 

OPERABLE status.

72 hours

C. One 

Function X 

subsystem 

inoperable.

AND

One 

Function Y 

subsystem 

inoperable.

C.1 Restore Function X 

subsystem to 

OPERABLE status.

OR

C.2 Restore Function Y 

subsystem to 

OPERABLE status.

72 hours

72 hours

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 

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).
Completion Times

1.3

General Electric BWR/6 STS 1.3-6 Rev. 4.0

1.3 Completion Times

EXAMPLES (continued)

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 

valves 

inoperable.

A.1 Restore valve(s) to 

OPERABLE status.

4 hours

B. Required 

Action and 

associated 

Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

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.
Completion Times

1.3

General Electric BWR/6 STS 1.3-7 Rev. 4.0

1.3 Completion Times

EXAMPLES (continued)

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 hours provided this does not result in any subsequent valve being 

inoperable for > 4 hours.

If the Completion Time of 4 hours (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 

valves 

inoperable.

A.1 Restore valve to 

OPERABLE status.

4 hours

B. Required 

Action and 

associated 

Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

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.
Completion Times

1.3

General Electric BWR/6 STS 1.3-8 Rev. 4.0

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 

inoperable.

A.1 Perform SR 3.x.x.x.

OR

A.2 Reduce THERMAL 

POWER to 

 50% RTP.

Once per 8 hours

8 hours

B. Required 

Action and 

associated 

Completion 

Time not met.

B.1 Be in MODE 3. 12 hours

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 hour interval of Required Action A.1 
Completion Times

1.3

General Electric BWR/6 STS 1.3-9 Rev. 4.0

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 hour 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 hours 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 

subsystem 

inoperable.

A.1 Verify affected 

subsystem isolated.

AND

A.2 Restore subsystem 

to OPERABLE 

status.

1 hour

AND

Once per 8 hours 

thereafter

72 hours

B. Required 

Action and 

associated 

Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

Required Action A.1 has two Completion Times. The 1 hour Completion 

Time begins at the time the Condition is entered and each "Once per 

8 hours thereafter" interval begins upon performance of Required 

Action A.1.
Completion Times

1.3

General Electric BWR/6 STS 1.3-10 Rev. 4.0

1.3 Completion Times

EXAMPLES (continued)

If after Condition A is entered, Required Action A.1 is not met within either 

the initial 1 hour or any subsequent 8 hour 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.

IMMEDIATE When "Immediately" is used as a Completion Time, the Required Action 

COMPLETION TIME should be pursued without delay and in a controlled manner.
Frequency

1.4

General Electric BWR/6 STS 1.4-1 Rev. 4.0

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
Frequency

1.4

General Electric BWR/6 STS 1.4-2 Rev. 4.0

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 hours

Example 1.4-1 contains the type of SR most often encountered in the 

Technical Specifications (TS). The Frequency specifies an interval 

(12 hours) 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 hours, 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.
Frequency

1.4

General Electric BWR/6 STS 1.4-3 Rev. 4.0

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 hours after 

 25% RTP

AND

24 hours 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 hours.

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.
Frequency

1.4

General Electric BWR/6 STS 1.4-4 Rev. 4.0

1.4 Frequency

EXAMPLES (continued)

EXAMPLE 1.4-3

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

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

Not required to be performed until 12 hours 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 hours 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 hours (plus the extension allowed by SR 3.0.2) with power 

 25% RTP.

Once the unit reaches 25% RTP, 12 hours would be allowed for 

completing the Surveillance. If the Surveillance were not performed 

within this 12 hour 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.
Frequency

1.4

General Electric BWR/6 STS 1.4-5 Rev. 4.0

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 hours

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 hour 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 hour Frequency exceeded, provided the MODE change was 

not made into MODE 1. Prior to entering MODE 1 (assuming again that 

the 24 hour Frequency were not met), SR 3.0.4 would require satisfying 

the SR.
Frequency

1.4

General Electric BWR/6 STS 1.4-6 Rev. 4.0

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.
Frequency

1.4

General Electric BWR/6 STS 1.4-7 Rev. 4.0

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 hours

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 hour 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 hour Frequency exceeded, provided the MODE change 

does not result in entry into MODE 2. Prior to entering MODE 2 

(assuming again that the 24 hour Frequency were not met), SR 3.0.4 

would require satisfying the SR.

SLs

2.0

General Electric BWR/6 STS 2.0-1 Rev. 4.0

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 hours:

2.2.1 Restore compliance with all SLs; and

2.2.2 Insert all insertable control rods.

LCO Applicability

3.0

General Electric BWR/6 STS 3.0-1 Rev. 4.0

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 hour 

to place the unit, as applicable, in:

a. MODE 2 within 7 hours,

b. MODE 3 within 13 hours, and

c. MODE 4 within 37 hours.

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.
LCO Applicability

3.0

General Electric BWR/6 STS 3.0-2 Rev. 4.0

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 5.5.12, "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:
LCO Applicability

3.0

General Electric BWR/6 STS 3.0-3 Rev. 4.0

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 hours; 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 hours. 

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 hours 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.
SR Applicability

3.0

General Electric BWR/6 STS 3.0-4 Rev. 4.0

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 hours 

or up to the limit of the specified Frequency, whichever is greater. This 

delay period is permitted to allow performance of the Surveillance. A risk 

evaluation shall be performed for any Surveillance delayed greater than 

24 hours 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.
SR Applicability

3.0

General Electric BWR/6 STS 3.0-5 Rev. 4.0

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.

SDM

3.1.1

General Electric BWR/6 STS 3.1.1-1 Rev. 4.0

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 

MODE 1 or 2.

A.1 Restore SDM to within 

limits.

6 hours

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Be in MODE 3. 12 hours

C. SDM not within limits in 

MODE 3.

C.1 Initiate action to fully insert 

all insertable control rods.

Immediately

D. SDM not within limits in 

MODE 4.

D.1 Initiate action to fully insert 

all insertable control rods.

AND

D.2 Initiate action to restore 

[secondary containment] to 

OPERABLE status.

AND

Immediately

1 hour
SDM

3.1.1

General Electric BWR/6 STS 3.1.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D.3 [ Initiate action to restore 

one standby gas treatment 

(SGT) subsystem to 

OPERABLE status.

AND

D.4 Initiate action to restore 

isolation capability in each 

required [secondary 

containment] penetration 

flow path not isolated.

1 hour ]

1 hour

E. SDM not within limits in 

MODE 5.

E.1 Suspend CORE 

ALTERATIONS except for 

control rod insertion and 

fuel assembly removal.

AND

E.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

AND

E.3 Initiate action to restore 

[secondary containment] to 

OPERABLE status.

AND

Immediately

Immediately

1 hour
SDM

3.1.1

General Electric BWR/6 STS 3.1.1-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E.4 [ Initiate action to restore 

one SGT subsystem to 

OPERABLE status.

AND

E.5 Initiate action to restore 

isolation capability in each 

required [secondary 

containment] penetration 

flow path not isolated.

1 hour ]

1 hour

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 hours after 

criticality following 

fuel movement 

within the reactor 

pressure vessel 

or control rod 

replacement 

Reactivity Anomalies

3.1.2

General Electric BWR/6 STS 3.1.2-1 Rev. 4.0

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 

[difference] not within 

limit.

A.1 Restore core reactivity 

[difference] to within limit.

72 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3. 12 hours
Reactivity Anomalies

3.1.2

General Electric BWR/6 STS 3.1.2-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.2.1 Verify core reactivity [difference] between the 

[monitored core keff and the predicted core keff] is 

within ± 1% k/k. 

Once within 

24 hours after 

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
Control Rod OPERABILITY

3.1.3

General Electric BWR/6 STS 3.1.3-1 Rev. 4.0

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 

rod stuck.

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

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 

separation criteria are met.

AND

A.2 Disarm the associated 

control rod drive (CRD).

AND

Immediately

2 hours
Control Rod OPERABILITY

3.1.3

General Electric BWR/6 STS 3.1.3-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.3 Perform SR 3.1.3.2 for 

each withdrawn 

OPERABLE control rod.

AND

A.4 Perform SR 3.1.1.1.

24 hours from 

discovery of 

Condition A 

concurrent with 

THERMAL POWER 

greater than the low 

power setpoint 

(LPSP) of the Rod 

Pattern Controller

72 hours

B. Two or more withdrawn 

control rods stuck.

B.1 Be in MODE 3. 12 hours

C. One or more control 

rods inoperable for 

reasons other than 

Condition A or B.

C.1 ---------------NOTE--------------

Inoperable control rods may 

be bypassed in RACS in 

accordance with 

SR 3.3.2.1.9, if required, to 

allow insertion of inoperable 

control rod and continued

operation.

-------------------------------------

Fully insert inoperable 

control rod.

AND

C.2 Disarm the associated 

CRD.

3 hours

4 hours
Control Rod OPERABILITY

3.1.3

General Electric BWR/6 STS 3.1.3-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. ------------NOTE------------

Not applicable when 

THERMAL POWER 

> [10]% RTP.

---------------------------------

Two or more inoperable 

control rods not in 

compliance with banked 

position withdrawal 

sequence (BPWS) and 

not separated by two or 

more OPERABLE 

control rods.

D.1 Restore compliance with 

BPWS.

OR

D.2 Restore control rod to 

OPERABLE status.

4 hours

4 hours

E. ------------NOTE------------

[ Not applicable when 

THERMAL POWER 

> [10]% RTP.

---------------------------------

One or more groups with 

four or more inoperable 

control rods.

E.1 Restore the control rod to 

OPERABLE status.

4 hours ]

F. Required Action and 

associated Completion 

Time of Condition A, C, 

D, or E not met.

OR

Nine or more control 

rods inoperable.

F.1 Be in MODE 3. 12 hours
Control Rod OPERABILITY

3.1.3

General Electric BWR/6 STS 3.1.3-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.3.1 Determine the position of each control rod. [ 24 hours

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 

withdrawn to notch position [13] is  [ ] seconds.

In accordance 

with SR 3.1.4.1, 

SR 3.1.4.2,

SR 3.1.4.3, and 

SR 3.1.4.4
Control Rod OPERABILITY

3.1.3

General Electric BWR/6 STS 3.1.3-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.1.3.4 Verify each control rod does not go to the withdrawn 

overtravel position.

Each time the 

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

Control Rod Scram Times

3.1.4

General Electric BWR/6 STS 3.1.4-1 Rev. 4.0

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 

LCO not met.

A.1 Be in MODE 3. 12 hours

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 

of Table 3.1.4-1 with reactor steam dome pressure 

 [950] psig.

Prior to exceeding 

40% RTP after 

each reactor

shutdown 

 120 days
Control Rod Scram Times

3.1.4

General Electric BWR/6 STS 3.1.4-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.1.4.2 Verify, for a representative sample, each tested 

control rod scram time is within the limits of 

Table 3.1.4-1 with reactor steam dome pressure 

 [950] psig.

[ [200] days 

cumulative 

operation in 

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 

the limits of Table 3.1.4-1 with any reactor steam 

dome pressure.

Prior to declaring 

control rod 

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 

the limits of Table 3.1.4-1 with reactor steam dome 

pressure  [950] psig.

Prior to exceeding 

40% RTP after 

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
Control Rod Scram Times

3.1.4

General Electric BWR/6 STS 3.1.4-3 Rev. 4.0

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."

-------------------------------------------------------------------------------------------------------------------------------

NOTCH POSITION

SCRAM TIMES(a)(b)

(seconds)

REACTOR STEAM 

DOME PRESSURE(c)

[950] psig

REACTOR STEAM DOME 

PRESSURE(c)

[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.

Control Rod Scram Accumulators

3.1.5

General Electric BWR/6 STS 3.1.5-1 Rev. 4.0

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 

accumulator inoperable 

with reactor steam dome 

pressure  [900] psig.

A.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 

control rod scram time 

"slow."

OR

A.2 Declare the associated 

control rod inoperable.

8 hours

8 hours

B. Two or more control rod 

scram accumulators 

inoperable with reactor 

steam dome pressure 

 [900] psig.

B.1 Restore charging water 

header pressure to 

 [1520] psig.

AND

20 minutes from 

discovery of 

Condition B 

concurrent with 

charging water 

header pressure 

< [1520] psig
Control Rod Scram Accumulators

3.1.5

General Electric BWR/6 STS 3.1.5-2 Rev. 4.0

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 

control rod scram time 

"slow."

OR

B.2.2 Declare the associated 

control rod inoperable.

1 hour

1 hour

C. One or more control rod 

scram accumulators 

inoperable with reactor 

steam dome pressure 

< [900] psig.

C.1 Verify all control rods 

associated with inoperable 

accumulators are fully 

inserted.

AND

C.2 Declare the associated 

control rod inoperable.

Immediately upon 

discovery of charging 

water header 

pressure 

< [1520] psig

1 hour

D. Required Action and 

associated Completion 

Time of Required 

Action B.1 or C.1 not 

met.

D.1 ---------------NOTE--------------

Not applicable if all 

inoperable control rod 

scram accumulators are 

associated with fully 

inserted control rods.

-------------------------------------

Place the reactor mode 

switch in the shutdown 

position.

Immediately
Control Rod Scram Accumulators

3.1.5

General Electric BWR/6 STS 3.1.5-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.5.1 Verify each control rod scram accumulator pressure 

is  [1520] psig.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Rod Pattern Control

3.1.6

General Electric BWR/6 STS 3.1.6-1 Rev. 4.0

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 

OPERABLE control rods 

not in compliance with 

[BPWS].

A.1 ---------------NOTE--------------

Affected control rods may 

be bypassed in Rod Action 

Control System (RACS) in 

accordance with 

SR 3.3.2.1.8.

-------------------------------------

Move associated control 

rod(s) to correct position.

OR

A.2 Declare associated control 

rod(s) inoperable.

8 hours

8 hours

B. Nine or more 

OPERABLE control rods 

not in compliance with 

[BPWS].

B.1 ---------------NOTE--------------

Affected control rods may 

be bypassed in RACS in 

accordance with 

SR 3.3.2.1.8 for insertion 

only.

-------------------------------------

Suspend withdrawal of 

control rods.

AND

Immediately
Rod Pattern Control

3.1.6

General Electric BWR/6 STS 3.1.6-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2 Place the reactor mode 

switch in the shutdown 

position.

1 hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.6.1 Verify all OPERABLE control rods comply with 

[BPWS].

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SLC System

3.1.7

General Electric BWR/6 STS 3.1.7-1 Rev. 4.0

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 

in solution not within 

limits but > [ ].

A.1 Restore concentration of 

boron in solution to within 

limits.

72 hours ]

B. One SLC subsystem 

inoperable [for reasons 

other than Condition A].

B.1 Restore SLC subsystem to 

OPERABLE status.

7 days

C. Two SLC subsystems 

inoperable [for reasons 

other than Condition A].

C.1 Restore one SLC 

subsystem to OPERABLE 

status.

8 hours

D. Required Action and 

associated Completion 

Time not met.

D.1 Be in MODE 3. 12 hours
SLC System

3.1.7

General Electric BWR/6 STS 3.1.7-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.7.1 Verify available volume of sodium pentaborate 

solution is [ [4530] gallons].

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.1.7.2 [ Verify temperature of sodium pentaborate solution 

is within the limits of [Figure 3.1.7-1].

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.1.7.3 [ Verify temperature of pump suction piping is within 

the limits of [Figure 3.1.7-1].

[ 24 hours

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 ]
SLC System

3.1.7

General Electric BWR/6 STS 3.1.7-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.1.7.5 Verify the concentration of boron in solution is 

[within the limits of Figure 3.1.7-1].

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

AND

Once within 

24 hours after 

water or boron is 

added to solution

AND

Once within 

24 hours 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 

operated, [and automatic valve] in the flow path that 

is not locked, sealed, or otherwise secured in 

position is in the correct position, or can be aligned 

to the correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SLC System

3.1.7

General Electric BWR/6 STS 3.1.7-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.1.7.7 Verify each pump develops a flow rate  [41.2] gpm 

at a discharge pressure  [1300] psig.

[ In accordance 

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 

into reactor pressure vessel.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SLC System

3.1.7

General Electric BWR/6 STS 3.1.7-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.1.7.9 [ Verify all heat traced piping between storage tank 

and pump suction is unblocked.

[ [18] months

AND

Once within 

24 hours 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 

 [60.0] atom percent B-10.

Prior to addition to 

SLC tank ]
SLC System

3.1.7

General Electric BWR/6 STS 3.1.7-6 Rev. 4.0
SDV Vent and Drain Valves

3.1.8

General Electric BWR/6 STS 3.1.8-1 Rev. 4.0

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 

or drain lines with one 

valve inoperable.

A.1 Isolate the associated line. 7 days

B. One or more SDV vent 

or drain lines with both 

valves inoperable.

B.1 Isolate the associated line. 8 hours

C. Required Action and 

associated Completion 

Time not met.

C.1 Be in MODE 3. 12 hours
SDV Vent and Drain Valves

3.1.8

General Electric BWR/6 STS 3.1.8-2 Rev. 4.0

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 

closed and fully open position.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.1.8.3 Verify each SDV vent and drain valve:

a. Closes in  [30] seconds after receipt of an 

actual or simulated scram signal and

b. Opens when the actual or simulated scram 

signal is reset.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
APLHGR

3.2.1

General Electric BWR/6 STS 3.2.1-1 Rev. 4.0

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 

limits.

A.1 Restore APLHGR(s) to 

within limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours
APLHGR

3.2.1

General Electric BWR/6 STS 3.2.1-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.2.1.1 Verify all APLHGRs are less than or equal to the 

limits specified in the COLR.

Once within 

12 hours after 

 25% RTP

AND

[ 24 hours 

thereafter

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
MCPR

3.2.2

General Electric BWR/6 STS 3.2.2-1 Rev. 4.0

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 

limits.

A.1 Restore MCPR(s) to within 

limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours
MCPR

3.2.2

General Electric BWR/6 STS 3.2.2-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.2.2.1 Verify all MCPRs are greater than or equal to the 

limits specified in the COLR.

Once within 

12 hours after 

 25% RTP

AND

[ 24 hours 

thereafter

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
LHGR (Optional)

3.2.3

General Electric BWR/6 STS 3.2.3-1 Rev. 4.0

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 

limits.

A.1 Restore LHGR(s) to within 

limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits 

specified in the COLR.

Once within 

12 hours after 

 25% RTP

AND

[ 24 hours 

thereafter

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

APRM Gain and Setpoints (Optional)

3.2.4

General Electric BWR/6 STS 3.2.4-1 Rev. 4.0

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 

LCO not met.

A.1 Satisfy the requirements of 

the LCO.

6 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours
APRM Gain and Setpoints (Optional)

3.2.4

General Electric BWR/6 STS 3.2.4-2 Rev. 4.0

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 hours after 

 25% RTP

AND

[ 24 hours 

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 

calculated MFLPD.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.1.1A Reactor Protection System (RPS) Instrumentation (Without Setpoint Control 

Program)

LCO 3.3.1.1A 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 

channels inoperable.

A.1 Place channel in trip.

OR

A.2 Place associated trip 

system in trip.

12 hours

12 hours

B. One or more Functions 

with one or more 

required channels 

inoperable in both trip 

systems.

B.1 Place channel in one trip 

system in trip.

OR

B.2 Place one trip system in 

trip.

6 hours

6 hours

C. One or more Functions 

with RPS trip capability 

not maintained.

C.1 Restore RPS trip capability. 1 hour

D. Required Action and 

associated Completion 

Time of Condition A, B, 

or C not met.

D.1 Enter the Condition 

referenced in 

Table 3.3.1.1-1 for the 

channel.

Immediately
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

E.1 Reduce THERMAL 

POWER to < [40]% RTP.

4 hours

F. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

F.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

G. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

G.1 Be in MODE 2. 6 hours

H. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

H.1 Be in MODE 3. 12 hours

I. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

I.1 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-3 Rev. 4.0

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 hours provided the associated Function maintains RPS trip capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.1.1.1 Perform CHANNEL CHECK. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.1.2 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

THERMAL POWER  25% RTP.

---------------------------------------------------------------------

Verify the absolute difference between the average 

power range monitor (APRM) channels and the 

calculated power  2% RTP [plus any gain 

adjustment required by LCO 3.2.4, "Average Power 

Range Monitor (APRM) Gain and Setpoints"] while 

operating at  25% RTP.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.1.3 Adjust the channel to conform to a calibrated flow 

signal.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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

Not required to be performed when entering 

MODE 2 from MODE 1 until 12 hours after entering 

MODE 2.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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 ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 ] ]

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 hours after entering MODE 2.

---------------------------------------------------------------------

Perform CHANNEL CALIBRATION. [ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.1.1.10 Perform CHANNEL FUNCTIONAL TEST. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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 hours 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 

Power - High time constant is  [7] seconds.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-7 Rev. 4.0

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 

- Low and Turbine Control Valve Fast Closure Trip 

Oil Pressure - Low Functions are not bypassed 

when THERMAL POWER is  [40]% RTP.

[ [18] months

OR

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 ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-8 Rev. 4.0

Table 3.3.1.1-1 (page 1 of 5)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Intermediate Range 

Monitors

a. Neutron Flux – High 2 [3] H SR 3.3.1.1.1

SR 3.3.1.1.4

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13

 [122/125] 

divisions of full 

scale

5

(c) [3] I SR 3.3.1.1.1

SR 3.3.1.1.5

SR 3.3.1.1.11(a)(b)

SR 3.3.1.1.13

 [122/125] 

divisions of full 

scale

b. Inop 2 [3] H SR 3.3.1.1.4

SR 3.3.1.1.13

NA

5

(c)

[3] I SR 3.3.1.1.5

SR 3.3.1.1.13

NA

2. Average Power Range 

Monitors

a. Neutron Flux - High, 

Setdown

2 [3] H SR 3.3.1.1.1

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

 [20]% RTP

(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.
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-9 Rev. 4.0

Table 3.3.1.1-1 (page 2 of 5)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

2. Average Power Range 

Monitors (Continued)

b. Flow Biased 

Simulated Thermal 

Power - High

1 [3] G SR 3.3.1.1.1

SR 3.3.1.1.2

SR 3.3.1.1.3

SR 3.3.1.1.6

SR 3.3.1.1.7

SR 3.3.1.1.9(a)(b)

SR 3.3.1.1.12(a)(b)

SR 3.3.1.1.13

SR 3.3.1.1.15

 [0.66 W + 

67]% RTP

and  [113]% 

RTP[(d)]

c. Fixed Neutron Flux -

High

1 [3] G SR 3.3.1.1.1

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

 [120]% RTP

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

SR 3.3.1.1.7

SR 3.3.1.1.13

NA

3. Reactor Vessel Steam 

Dome Pressure - High

1,2 [2] H SR 3.3.1.1.1

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

 [1079.7] psig

(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." ]
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-10 Rev. 4.0

Table 3.3.1.1-1 (page 3 of 5)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

4. Reactor Vessel Water 

Level - Low, Level 3

1,2 [2] H SR 3.3.1.1.1

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

 [10.8] inches

5. Reactor Vessel Water 

Level - High, Level 8

 25% RTP [2] F SR 3.3.1.1.1

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

 [54.1] inches

6. Main Steam Isolation 

Valve - Closure

1 [8] G SR 3.3.1.1.9

SR 3.3.1.1.11

SR 3.3.1.1.13

SR 3.3.1.1.15

 [7]% closed

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

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

 [1.43] psig

(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].
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-11 Rev. 4.0

Table 3.3.1.1-1 (page 4 of 5)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

8. Scram Discharge 

Volume Water Level -

High

a. Transmitter/Trip Unit 1,2 [2] H SR 3.3.1.1.1

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

 [63]% of full 

scale

5

(c)

[2] I SR 3.3.1.1.1

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

 [63]% of full 

scale

b. Float Switch 1,2 [2] H SR 3.3.1.1.7

SR 3.3.1.1.11

SR 3.3.1.1.13

 [65] inches

5

(c)

[2] I SR 3.3.1.1.7

SR 3.3.1.1.11

SR 3.3.1.1.13

 [65] inches

9. Turbine Stop Valve 

Closure, Trip Oil 

Pressure - Low

 [40]% RTP [4] E 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 3.3.1.1.14

SR 3.3.1.1.15

 [37] psig

10. Turbine Control Valve 

Fast Closure, Trip Oil 

Pressure - Low

 [40]% RTP [2] E 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 3.3.1.1.14

SR 3.3.1.1.15

 [42] psig

(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.
RPS Instrumentation (Without Setpoint Control Program)

3.3.1.1A

General Electric BWR/6 STS 3.3.1.1A-12 Rev. 4.0

Table 3.3.1.1-1 (page 5 of 5)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

11. Reactor Mode Switch -

Shutdown Position

1,2 [2] H SR 3.3.1.1.10

SR 3.3.1.1.13

NA

5

(c)

[2] I SR 3.3.1.1.10

SR 3.3.1.1.13

NA

12. Manual Scram 1,2 [2] H SR 3.3.1.1.5

SR 3.3.1.1.13

NA

5

(c)

[2] I SR 3.3.1.1.5

SR 3.3.1.1.13

NA

(c) With any control rod withdrawn from a core cell containing one or more fuel assemblies.
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.1.1B Reactor Protection System (RPS) Instrumentation (With Setpoint Control Program)

LCO 3.3.1.1B 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 

channels inoperable.

A.1 Place channel in trip.

OR

A.2 Place associated trip 

system in trip.

12 hours

12 hours

B. One or more Functions 

with one or more 

required channels 

inoperable in both trip 

systems.

B.1 Place channel in one trip 

system in trip.

OR

B.2 Place one trip system in 

trip.

6 hours

6 hours

C. One or more Functions 

with RPS trip capability 

not maintained.

C.1 Restore RPS trip capability. 1 hour

D. Required Action and 

associated Completion 

Time of Condition A, B, 

or C not met.

D.1 Enter the Condition 

referenced in 

Table 3.3.1.1-1 for the 

channel.

Immediately
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

E.1 Reduce THERMAL 

POWER to < [40]% RTP.

4 hours

F. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

F.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

G. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

G.1 Be in MODE 2. 6 hours

H. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

H.1 Be in MODE 3. 12 hours

I. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1.

I.1 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-3 Rev. 4.0

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 hours provided the associated Function maintains RPS trip capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.1.1.1 Perform CHANNEL CHECK. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.1.2 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

THERMAL POWER  25% RTP.

---------------------------------------------------------------------

Verify the absolute difference between the average 

power range monitor (APRM) channels and the 

calculated power  2% RTP [plus any gain 

adjustment required by LCO 3.2.4, "Average Power 

Range Monitor (APRM) Gain and Setpoints"] while 

operating at  25% RTP.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.1.3 Adjust the channel to conform to a calibrated flow 

signal.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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

Not required to be performed when entering 

MODE 2 from MODE 1 until 12 hours after entering 

MODE 2.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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 ]
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

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 hours after entering MODE 2.

---------------------------------------------------------------------

Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.1.1.10 Perform CHANNEL FUNCTIONAL TEST. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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 hours after entering MODE 2.

---------------------------------------------------------------------

Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.1.12 Verify the APRM Flow Biased Simulated Thermal 

Power - High time constant is  [7] seconds in 

accordance with the Setpoint Control Program.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-7 Rev. 4.0

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 

- Low and Turbine Control Valve Fast Closure Trip 

Oil Pressure - Low Functions are not bypassed 

when THERMAL POWER is  [40]% RTP.

[ [18] months

OR

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 ]
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-8 Rev. 4.0

Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

1. Intermediate Range Monitors

a. Neutron Flux – High 2 [3] H SR 3.3.1.1.1

SR 3.3.1.1.4

SR 3.3.1.1.11

SR 3.3.1.1.13

5

(a) [3] I SR 3.3.1.1.1

SR 3.3.1.1.5

SR 3.3.1.1.11

SR 3.3.1.1.13

b. Inop 2 [3] H SR 3.3.1.1.4

SR 3.3.1.1.13

5

(a) [3] I SR 3.3.1.1.5

SR 3.3.1.1.13

2. Average Power Range Monitors

a. Neutron Flux - High, Setdown 2 [3] H SR 3.3.1.1.1

SR 3.3.1.1.4

SR 3.3.1.1.6

SR 3.3.1.1.9

SR 3.3.1.1.13

b. Flow Biased Simulated Thermal 

Power - High

1 [3] G SR 3.3.1.1.1

SR 3.3.1.1.2

SR 3.3.1.1.3

SR 3.3.1.1.6

SR 3.3.1.1.7

SR 3.3.1.1.9

SR 3.3.1.1.12

SR 3.3.1.1.13

SR 3.3.1.1.15

c. Fixed Neutron Flux - High 1 [3] G SR 3.3.1.1.1

SR 3.3.1.1.2

SR 3.3.1.1.6

SR 3.3.1.1.7

SR 3.3.1.1.9

SR 3.3.1.1.13

SR 3.3.1.1.15

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

SR 3.3.1.1.7

SR 3.3.1.1.13

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-9 Rev. 4.0

Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

3. Reactor Vessel Steam Dome Pressure -

High

1,2 [2] H SR 3.3.1.1.1

SR 3.3.1.1.7 

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

SR 3.3.1.1.15

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

SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

SR 3.3.1.1.15

5. Reactor Vessel Water Level - High, 

Level 8

 25% RTP [2] F SR 3.3.1.1.1

SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

SR 3.3.1.1.15

6. Main Steam Isolation Valve - Closure 1 [8] G SR 3.3.1.1.9

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

SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

8. Scram Discharge Volume Water Level -

High

a. Transmitter/Trip Unit 1,2 [2] H SR 3.3.1.1.1

SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

5

(a) [2] I SR 3.3.1.1.1

SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.
RPS Instrumentation (With Setpoint Control Program)

3.3.1.1B

General Electric BWR/6 STS 3.3.1.1B-10 Rev. 4.0

Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1

SURVEILLANCE

REQUIREMENTS

8. Scram Discharge Volume Water Level -

High

b. Float Switch 1,2 [2] H SR 3.3.1.1.7

SR 3.3.1.1.11

SR 3.3.1.1.13

5

(a) [2] I SR 3.3.1.1.7

SR 3.3.1.1.11

SR 3.3.1.1.13

9. Turbine Stop Valve Closure, Trip Oil 

Pressure - Low

 [40]% RTP [4] E SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

SR 3.3.1.1.14

SR 3.3.1.1.15

10. Turbine Control Valve Fast Closure, Trip 

Oil Pressure - Low

 [40]% RTP [2] E SR 3.3.1.1.7

[SR 3.3.1.1.8]

SR 3.3.1.1.11

SR 3.3.1.1.13

SR 3.3.1.1.14

SR 3.3.1.1.15

11. Reactor Mode Switch - Shutdown Position 1,2 [2] H SR 3.3.1.1.10

SR 3.3.1.1.13

5

(a) [2] I SR 3.3.1.1.10

SR 3.3.1.1.13

12. Manual Scram 1,2 [2] H SR 3.3.1.1.5

SR 3.3.1.1.13

5

(a) [2] I SR 3.3.1.1.5

SR 3.3.1.1.13

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.
SRM Instrumentation (Without Setpoint Control Program)

3.3.1.2A

General Electric BWR/6 STS 3.3.1.2A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.1.2A Source Range Monitor (SRM) Instrumentation (Without Setpoint Control Program)

LCO 3.3.1.2A 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 

SRMs inoperable in 

MODE 2 with 

intermediate range 

monitors (IRMs) on 

Range 2 or below.

A.1 Restore required SRMs to 

OPERABLE status.

4 hours

B. [Four] required SRMs 

inoperable in MODE 2 

with IRMs on Range 2 or 

below.

B.1 Suspend control rod 

withdrawal.

Immediately

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1 Be in MODE 3. 12 hours

D. One or more required 

SRMs inoperable in 

MODE 3 or 4.

D.1 Fully insert all insertable 

control rods.

AND

D.2 Place reactor mode switch 

in the shutdown position.

1 hour

1 hour
SRM Instrumentation (Without Setpoint Control Program)

3.3.1.2A

General Electric BWR/6 STS 3.3.1.2A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. One or more required 

SRMs inoperable in 

MODE 5.

E.1 Suspend CORE 

ALTERATIONS except for 

control rod insertion.

AND

E.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately

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 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (Without Setpoint Control Program)

3.3.1.2A

General Electric BWR/6 STS 3.3.1.2A-3 Rev. 4.0

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:

a. The fueled region,

b. The core quadrant where CORE 

ALTERATIONS are being performed when the 

associated SRM is included in the fueled 

region, and

c. A core quadrant adjacent to where CORE 

ALTERATIONS are being performed, when the 

associated SRM is included in the fueled 

region.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.2.3 Perform CHANNEL CHECK. [ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (Without Setpoint Control Program)

3.3.1.2A

General Electric BWR/6 STS 3.3.1.2A-4 Rev. 4.0

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:

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

b.  [0.7] cps with a signal to noise ratio  [20:1].

[ 12 hours

during CORE 

ALTERATIONS

AND

24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST [and 

determination of signal to noise ratio].

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (Without Setpoint Control Program)

3.3.1.2A

General Electric BWR/6 STS 3.3.1.2A-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.1.2.6 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

IRMs on Range 2 or below.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST [and 

determination of signal to noise ratio].

[ 31 days

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 hours 

after IRMs on Range 2 or below.

---------------------------------------------------------------------

Perform CHANNEL CALIBRATION. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (Without Setpoint Control Program)

3.3.1.2A

General Electric BWR/6 STS 3.3.1.2A-6 Rev. 4.0

Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation

FUNCTION

APPLICABLE

MODES OR OTHER 

SPECIFIED 

CONDITIONS

REQUIRED

CHANNELS

SURVEILLANCE

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.
SRM Instrumentation (With Setpoint Control Program)

3.3.1.2B

General Electric BWR/6 STS 3.3.1.2B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.1.2B Source Range Monitor (SRM) Instrumentation (With Setpoint Control Program)

LCO 3.3.1.2B 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 

SRMs inoperable in 

MODE 2 with 

intermediate range 

monitors (IRMs) on 

Range 2 or below.

A.1 Restore required SRMs to 

OPERABLE status.

4 hours

B. [Four] required SRMs 

inoperable in MODE 2 

with IRMs on Range 2 or 

below.

B.1 Suspend control rod 

withdrawal.

Immediately

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1 Be in MODE 3. 12 hours

D. One or more required 

SRMs inoperable in 

MODE 3 or 4.

D.1 Fully insert all insertable 

control rods.

AND

D.2 Place reactor mode switch 

in the shutdown position.

1 hour

1 hour
SRM Instrumentation (With Setpoint Control Program)

3.3.1.2B

General Electric BWR/6 STS 3.3.1.2B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. One or more required 

SRMs inoperable in 

MODE 5.

E.1 Suspend CORE 

ALTERATIONS except for 

control rod insertion.

AND

E.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately

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 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (With Setpoint Control Program)

3.3.1.2B

General Electric BWR/6 STS 3.3.1.2B-3 Rev. 4.0

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:

a. The fueled region,

b. The core quadrant where CORE 

ALTERATIONS are being performed when the 

associated SRM is included in the fueled 

region, and

c. A core quadrant adjacent to where CORE 

ALTERATIONS are being performed, when the 

associated SRM is included in the fueled 

region.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.2.3 Perform CHANNEL CHECK. [ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (With Setpoint Control Program)

3.3.1.2B

General Electric BWR/6 STS 3.3.1.2B-4 Rev. 4.0

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:

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

b.  [0.7] cps with a signal to noise ratio  [20:1].

[ 12 hours

during CORE 

ALTERATIONS

AND

24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST [and 

determination of signal to noise ratio].

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (With Setpoint Control Program)

3.3.1.2B

General Electric BWR/6 STS 3.3.1.2B-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.1.2.6 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

IRMs on Range 2 or below.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST [and 

determination of signal to noise ratio].

[ 31 days

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 hours 

after IRMs on Range 2 or below.

---------------------------------------------------------------------

Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SRM Instrumentation (With Setpoint Control Program)

3.3.1.2B

General Electric BWR/6 STS 3.3.1.2B-6 Rev. 4.0

Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation

FUNCTION

APPLICABLE

MODES OR OTHER 

SPECIFIED 

CONDITIONS

REQUIRED

CHANNELS

SURVEILLANCE

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.
Control Rod Block Instrumentation (Without Setpoint Control Program)

3.3.2.1A

General Electric BWR/6 STS 3.3.2.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.2.1A Control Rod Block Instrumentation (Without Setpoint Control Program)

LCO 3.3.2.1A 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 

withdrawal limiter (RWL) 

channels inoperable.

A.1 Suspend control rod 

withdrawal.

Immediately

B. One or more rod pattern 

controller channels 

inoperable.

B.1 Suspend control rod 

movement except by 

scram.

Immediately

C. One or more Reactor 

Mode Switch - Shutdown 

Position channels 

inoperable.

C.1 Suspend control rod 

withdrawal.

AND

C.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately
Control Rod Block Instrumentation (Without Setpoint Control Program)

3.3.2.1A

General Electric BWR/6 STS 3.3.2.1A-2 Rev. 4.0

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 hours 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 hour 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 hour after 

THERMAL POWER is > 35% RTP and  70% RTP.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Control Rod Block Instrumentation (Without Setpoint Control Program)

3.3.2.1A

General Electric BWR/6 STS 3.3.2.1A-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.2.1.3 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour 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 hour 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 ]
Control Rod Block Instrumentation (Without Setpoint Control Program)

3.3.2.1A

General Electric BWR/6 STS 3.3.2.1A-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.2.1.6 Verify the RWL high power Function is not bypassed 

when THERMAL POWER is > [70]% RTP.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.2.1.7 Perform CHANNEL CALIBRATION. The Allowable 

Value shall be:

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

 [35]% RTP and

b. High power setpoint,  [70]% RTP.

[ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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

Not required to be performed until 1 hour 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 

required to be bypassed in Rod Action Control 

System (RACS) by a second licensed operator or 

other qualified member of the technical staff.

Prior to and 

during the 

movement of 

control rods 

bypassed in 

RACS
Control Rod Block Instrumentation (Without Setpoint Control Program)

3.3.2.1A

General Electric BWR/6 STS 3.3.2.1A-5 Rev. 4.0

Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation

FUNCTION

APPLICABLE

MODES OR OTHER 

SPECIFIED 

CONDITIONS

REQUIRED

CHANNELS

SURVEILLANCE

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.

Control Rod Block Instrumentation (With Setpoint Control Program)

3.3.2.1B

General Electric BWR/6 STS 3.3.2.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.2.1B Control Rod Block Instrumentation (With Setpoint Control Program)

LCO 3.3.2.1B 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 

withdrawal limiter (RWL) 

channels inoperable.

A.1 Suspend control rod 

withdrawal.

Immediately

B. One or more rod pattern 

controller channels 

inoperable.

B.1 Suspend control rod 

movement except by 

scram.

Immediately

C. One or more Reactor 

Mode Switch - Shutdown 

Position channels 

inoperable.

C.1 Suspend control rod 

withdrawal.

AND

C.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately
Control Rod Block Instrumentation (With Setpoint Control Program)

3.3.2.1B

General Electric BWR/6 STS 3.3.2.1B-2 Rev. 4.0

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 hours 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 hour 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 hour after 

THERMAL POWER is > 35% RTP and  70% RTP.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Control Rod Block Instrumentation (With Setpoint Control Program)

3.3.2.1B

General Electric BWR/6 STS 3.3.2.1B-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.2.1.3 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour 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 hour 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 in accordance with the 

Setpoint Control Program.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Control Rod Block Instrumentation (With Setpoint Control Program)

3.3.2.1B

General Electric BWR/6 STS 3.3.2.1B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.2.1.6 Verify the RWL high power Function is not bypassed 

when THERMAL POWER is > [70]% RTP.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.2.1.7 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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

Not required to be performed until 1 hour 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 

required to be bypassed in Rod Action Control 

System (RACS) by a second licensed operator or 

other qualified member of the technical staff.

Prior to and 

during the 

movement of 

control rods 

bypassed in 

RACS
Control Rod Block Instrumentation (With Setpoint Control Program)

3.3.2.1B

General Electric BWR/6 STS 3.3.2.1B-5 Rev. 4.0

Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation

FUNCTION

APPLICABLE

MODES OR OTHER 

SPECIFIED 

CONDITIONS

REQUIRED

CHANNELS

SURVEILLANCE

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)] 2 SR 3.3.2.1.2

SR 3.3.2.1.5

SR 3.3.2.1.7

b. Rod pattern controller 1

(c), 2(c) 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 (d) 2 SR 3.3.2.1.8

(a) THERMAL POWER > [70]% RTP.

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

(c) With THERMAL POWER  [10]% RTP [, except during the reactor shutdown process if the coupling of each 

withdrawn control rod has been confirmed].

(d) Reactor mode switch in the shutdown position.

PAM Instrumentation

3.3.3.1

General Electric BWR/6 STS 3.3.3.1-1 Rev. 4.0

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 

with one required 

channel inoperable.

A.1 Restore required channel to 

OPERABLE status.

30 days

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Initiate action in accordance 

with Specification 5.6.5.

Immediately

C. One or more Functions 

with two required 

channels inoperable.

C.1 Restore one required 

channel to OPERABLE 

status.

7 days

D. Required Action and 

associated Completion 

Time of Condition C not 

met.

D.1 Enter the Condition 

referenced in 

Table 3.3.3.1-1 for the 

channel.

Immediately
PAM Instrumentation

3.3.3.1

General Electric BWR/6 STS 3.3.3.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.3.1-1.

E.1 Be in MODE 3. 12 hours

F. [ As required by 

Required Action D.1 and 

referenced in 

Table 3.3.3.1-1.

F.1 Initiate action in accordance 

with Specification 5.6.5.

Immediately ]

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 ]
PAM Instrumentation

3.3.3.1

General Electric BWR/6 STS 3.3.3.1-3 Rev. 4.0

Table 3.3.3.1-1 (page 1 of 1)

Post Accident Monitoring Instrumentation

FUNCTION

REQUIRED

CHANNELS

CONDITIONS 

REFERENCED FROM 

REQUIRED 

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 

path(a) (c)

E

9. Wide Range Neutron Flux 2 E

10. Primary Containment Pressure 2 E

11. [Relief Valve Discharge Location] Suppression Pool 

Water Temperature

2

(c) E

(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.

------------------------------------------------------------------------------------------------------------------------------------------------------------

Remote Shutdown System

3.3.3.2

General Electric BWR/6 STS 3.3.3.2-1 Rev. 4.0

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 

Functions inoperable.

A.1 Restore required Function 

to OPERABLE status.

30 days

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.3.3.2.1 [ Perform CHANNEL CHECK for each required 

instrumentation channel that is normally energized.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
Remote Shutdown System

3.3.3.2

General Electric BWR/6 STS 3.3.3.2-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.3.2.2 Verify each required control circuit and transfer 

switch is capable of performing the intended 

functions.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each 

required instrumentation channel.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
EOC-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.1A

General Electric BWR/6 STS 3.3.4.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.4.1A End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation (Without Setpoint 

Control Program)

LCO 3.3.4.1A 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 

channels inoperable.

A.1 Restore channel to 

OPERABLE status.

OR

A.2 ---------------NOTE--------------

Not applicable if inoperable 

channel is the result of an 

inoperable breaker.

-------------------------------------

Place channel in trip.

72 hours

72 hours
EOC-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.1A

General Electric BWR/6 STS 3.3.4.1A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. One or more Functions 

with EOC-RPT trip 

capability not 

maintained.

AND

[MCPR limit for 

inoperable EOC-RPT 

not made applicable.]

B.1 Restore EOC-RPT trip 

capability.

OR

[ B.2 Apply the MCPR limit for 

inoperable EOC-RPT as 

specified in the COLR.

2 hours

2 hours ]

C. Required Action and 

associated Completion 

Time not met.

C.1 Remove the associated 

recirculation pump fast 

speed breaker from service.

OR

C.2 Reduce THERMAL 

POWER to < [40]% RTP.

4 hours

4 hours

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 hours, 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 ]
EOC-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.1A

General Electric BWR/6 STS 3.3.4.1A-3 Rev. 4.0

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 ] ]
EOC-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.1A

General Electric BWR/6 STS 3.3.4.1A-4 Rev. 4.0

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 asleft 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 

Values shall be:

a. TSV Closure, Trip Oil Pressure - Low: 

 [37] psig and

b. TCV Fast Closure, Trip Oil Pressure -

Low:  [42] psig.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
EOC-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.1A

General Electric BWR/6 STS 3.3.4.1A-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, 

including breaker actuation.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.4.1.5 Verify TSV Closure, Trip Oil Pressure - Low and 

TCV Fast Closure, Trip Oil Pressure - Low 

Functions are not bypassed when THERMAL 

POWER is  [40]% RTP.

[ [18] months

OR

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 

within limits.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
EOC-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.1A

General Electric BWR/6 STS 3.3.4.1A-6 Rev. 4.0

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 ]
EOC-RPT Instrumentation (With Setpoint Control Program)

3.3.4.1B

General Electric BWR/6 STS 3.3.4.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.4.1B End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation (With Setpoint 

Control Program)

LCO 3.3.4.1B 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 

channels inoperable.

A.1 Restore channel to 

OPERABLE status.

OR

A.2 ---------------NOTE--------------

Not applicable if inoperable 

channel is the result of an 

inoperable breaker.

-------------------------------------

Place channel in trip.

72 hours

72 hours
EOC-RPT Instrumentation (With Setpoint Control Program)

3.3.4.1B

General Electric BWR/6 STS 3.3.4.1B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. One or more Functions 

with EOC-RPT trip 

capability not 

maintained.

AND

[MCPR limit for 

inoperable EOC-RPT 

not made applicable.]

B.1 Restore EOC-RPT trip 

capability.

OR

[ B.2 Apply the MCPR limit for 

inoperable EOC-RPT as 

specified in the COLR.

2 hours

2 hours ]

C. Required Action and 

associated Completion 

Time not met.

C.1 Remove the associated 

recirculation pump fast 

speed breaker from service.

OR

C.2 Reduce THERMAL 

POWER to < [40]% RTP.

4 hours

4 hours

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 hours, 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 ]
EOC-RPT Instrumentation (With Setpoint Control Program)

3.3.4.1B

General Electric BWR/6 STS 3.3.4.1B-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.4.1.2 [ Calibrate the trip units in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.4.1.3 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program. 

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, 

including breaker actuation.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.4.1.5 Verify TSV Closure, Trip Oil Pressure - Low and 

TCV Fast Closure, Trip Oil Pressure - Low 

Functions are not bypassed when THERMAL 

POWER is  [40]% RTP.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
EOC-RPT Instrumentation (With Setpoint Control Program)

3.3.4.1B

General Electric BWR/6 STS 3.3.4.1B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 

within limits.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.4.1.7 Determine RPT breaker [interruption] time. [ 60 months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ATWS-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.2A

General Electric BWR/6 STS 3.3.4.2A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.4.2A Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) 

Instrumentation (Without Setpoint Control Program)

LCO 3.3.4.2A 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 

inoperable.

A.1 Restore channel to 

OPERABLE status.

OR

A.2 ---------------NOTE--------------

Not applicable if inoperable 

channel is the result of an 

inoperable breaker.

-------------------------------------

Place channel in trip.

14 days

14 days

B. One Function with 

ATWS-RPT trip 

capability not 

maintained.

B.1 Restore ATWS-RPT trip 

capability.

72 hours
ATWS-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.2A

General Electric BWR/6 STS 3.3.4.2A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Both Functions with 

ATWS-RPT trip 

capability not 

maintained.

C.1 Restore ATWS-RPT trip 

capability for one Function.

1 hour

D. Required Action and 

associated Completion 

Time not met.

D.1 ---------------NOTE--------------

Only applicable if 

inoperable channel is the 

result of an inoperable RPT 

breaker.

-------------------------------------

Remove the affected 

recirculation pump from 

service.

OR

D.2 Be in MODE 2.

6 hours

6 hours

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 hours provided the associated Function maintains ATWS-RPT trip capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.4.2.1 [ Perform CHANNEL CHECK. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
ATWS-RPT Instrumentation (Without Setpoint Control Program)

3.3.4.2A

General Electric BWR/6 STS 3.3.4.2A-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 ] ]

SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable 

Values shall be:

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

 [-43.8] inches and

b. Reactor Steam Dome Pressure - High: 

 [1102] psig.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, 

including breaker actuation.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

ATWS-RPT Instrumentation (With Setpoint Control Program)

3.3.4.2B

General Electric BWR/6 STS 3.3.4.2B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.4.2B Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) 

Instrumentation (With Setpoint Control Program)

LCO 3.3.4.2B 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 

inoperable.

A.1 Restore channel to 

OPERABLE status.

OR

A.2 ---------------NOTE--------------

Not applicable if inoperable 

channel is the result of an 

inoperable breaker.

-------------------------------------

Place channel in trip.

14 days

14 days

B. One Function with 

ATWS-RPT trip 

capability not 

maintained.

B.1 Restore ATWS-RPT trip 

capability.

72 hours
ATWS-RPT Instrumentation (With Setpoint Control Program)

3.3.4.2B

General Electric BWR/6 STS 3.3.4.2B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Both Functions with 

ATWS-RPT trip 

capability not 

maintained.

C.1 Restore ATWS-RPT trip 

capability for one Function.

1 hour

D. Required Action and 

associated Completion 

Time not met.

D.1 ---------------NOTE--------------

Only applicable if 

inoperable channel is the 

result of an inoperable RPT 

breaker.

-------------------------------------

Remove the affected 

recirculation pump from 

service.

OR

D.2 Be in MODE 2.

6 hours

6 hours

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 hours provided the associated Function maintains ATWS-RPT trip capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.4.2.1 [ Perform CHANNEL CHECK. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
ATWS-RPT Instrumentation (With Setpoint Control Program)

3.3.4.2B

General Electric BWR/6 STS 3.3.4.2B-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.4.2.4 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program. 

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, 

including breaker actuation.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.5.1A Emergency Core Cooling System (ECCS) Instrumentation (Without Setpoint Control 

Program)

LCO 3.3.5.1A 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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.5.1-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

B.1 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 1.a, 1.b, 2.a 

and 2.b.

-------------------------------------

Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable.

AND

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 3.a and 3.b.

-------------------------------------

Declare High Pressure 

Core Spray (HPCS) System 

inoperable.

AND

B.3 Place channel in trip.

1 hour from discovery 

of loss of HPCS 

initiation capability

24 hours

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

C.1 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 1.c, 1.d, 2.c, 

and 2.d.

-------------------------------------

Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable.

AND

C.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions

24 hours
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

D.1 ---------------NOTE--------------

Only applicable if HPCS 

pump suction is not aligned 

to the suppression pool.

-------------------------------------

Declare HPCS System 

inoperable.

AND

D.2.1 Place channel in trip.

 OR

D.2.2 Align the HPCS pump 

suction to the suppression 

pool.

1 hour from discovery 

of loss of HPCS 

initiation capability

24 hours

24 hours

E. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

E.1 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 1.e, 1.f, and 

2.e.

-------------------------------------

Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable.

AND

E.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions

7 days
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-4 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

F.1 Declare Automatic 

Depressurization System 

(ADS) valves inoperable.

AND

F.2 Place channel in trip.

1 hour from discovery 

of loss of ADS 

initiation capability in 

both trip systems

96 hours from 

discovery of 

inoperable channel 

concurrent with 

HPCS or reactor core 

isolation cooling 

(RCIC) inoperable

AND

8 days

G. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

G.1 ---------------NOTE--------------

Only applicable for 

Functions 4.c, 4.e, 4.f, 4.g, 

5.c, 5.e, and 5.f.

-------------------------------------

Declare ADS valves 

inoperable.

AND

G.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of ADS 

initiation capability in 

both trip systems

96 hours from 

discovery of 

inoperable channel 

concurrent with 

HPCS or RCIC 

inoperable

AND

8 days
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-5 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

H. Required Action and 

associated Completion 

Time of Condition B, C, 

D, E, F, or G not met.

H.1 Declare associated 

supported feature(s) 

inoperable.

Immediately

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 hours for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours 

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 hours

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 ]
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-6 Rev. 4.0

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 ]
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-7 Rev. 4.0

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 ]
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-8 Rev. 4.0

Table 3.3.5.1-1 (page 1 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Low Pressure Coolant 

Injection-A (LPCI) and 

Low Pressure Core 

Spray (LPCS) 

Subsystems

a. Reactor Vessel 

Water Level - Low 

Low Low, Level 1

1, 2, 3, 

4

(a)

, 5

(a)

[2](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

SR 3.3.5.1.7

 [-152.5]

inches

b. Drywell Pressure -

High

1, 2, 3 [2](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

SR 3.3.5.1.7

 [1.44] psig

c. LPCI Pump A Start -

Time Delay Relay

1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.2

[SR 3.3.5.1.4]

SR 3.3.5.1.6

 [ ] seconds 

and  [5.25]

seconds

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(b) Also required to initiate the associated [Technical Specifications (TS) required functions].

(c) 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.

(d) 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].
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-9 Rev. 4.0

Table 3.3.5.1-1 (page 2 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. LPCI and LPCS 

Subsystems

d. Reactor Steam 

Dome Pressure -

Low (Injection 

Permissive)

1, 2, 3 [3] C SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

 [452] psig 

and

 [534] psig

4

(a), 5(a) [3] B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

 [452] psig 

and

 [534] psig

e. [ LPCS Pump 

Discharge Flow -

Low (Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

 [ ] gpm and

 [ ] gpm

f. [ LPCI Pump A 

Discharge Flow -

Low (Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

 [ ] gpm and

 [ ] gpm

[ g. Manual Initiation 1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.6 NA ]

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-10 Rev. 4.0

Table 3.3.5.1-1 (page 3 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

2. LPCI B and LPCI C 

Subsystems

a. Reactor Vessel 

Water Level - Low 

Low Low, Level 1

1, 2, 3, 

4

(a)

, 5

(a)

[2](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

SR 3.3.5.1.7

 [-152.5] 

inches

b. Drywell Pressure -

High

1, 2, 3 [2](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

SR 3.3.5.1.7

 [1.44] psig

c. LPCI Pump B Start -

Time Delay Relay

1, 2, 3, 

4

(a) ,5(a)

[1] C SR 3.3.5.1.2

SR 3.3.5.1.4

SR 3.3.5.1.6

 [ ] seconds 

and

 [5.25] 

seconds

d. Reactor Steam 

Dome Pressure -

Low (Injection 

Permissive)

1, 2, 3 [3] C SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

 [452] psig 

and

 [534] psig

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(b) Also required to initiate the associated [Technical Specifications (TS) required functions].

(c) 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.

(d) 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].
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-11 Rev. 4.0

Table 3.3.5.1-1 (page 4 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

2. LPCI B and LPCI C 

Subsystems

e. [ LPCI Pump B 

and LPCI Pump C 

Discharge Flow -

Low (Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[2]

[1 per 

pump]

E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

 [ ] gpm

and

 [ ] gpm

[ f. Manual Initiation 1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.6 NA ]

3. High Pressure Core 

Spray (HPCS) System

a. Reactor Vessel 

Water Level - Low 

Low, Level 2

1, 2, 3, 

4

(a)

, 5

(a)

[4](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

SR 3.3.5.1.7

 [-43.8] inches

b. Drywell Pressure -

High

1, 2, 3 [4](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

SR 3.3.5.1.7

 [1.44] psig

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(b) Also required to initiate the associated [TS required functions].

(c) 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.

(d) 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].
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-12 Rev. 4.0

Table 3.3.5.1-1 (page 5 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

3. HPCS System

c. Reactor Vessel 

Water Level - High, 

Level 8

1, 2, 3, 

4

(a)

, 5

(a)

[2] C SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [55.7] inches

d. Condensate Storage 

Tank Level - Low

1, 2, 3, 

4

(e)

, 5

(e)

[2] D SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [-3] inches

e. Suppression Pool 

Water Level - High

1, 2, 3 [2] D SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [7.0] inches

f. [ HPCS Pump 

Discharge Pressure 

- High (Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [ ] psig

g. [ HPCS System 

Flow Rate - Low 

(Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [ ] gpm and 

 [ ] gpm

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(c) 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.

(d) 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) When HPCS is OPERABLE for compliance with LCO 3.5.2, "ECCS - Shutdown," and aligned to the condensate 

storage tank while tank water level is not within the limit of SR 3.5.2.2.
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-13 Rev. 4.0

Table 3.3.5.1-1 (page 6 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

3. HPCS System

[ h. Manual Initiation 1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.6 NA ]

4. ADS Trip System A 

a. Reactor Vessel 

Water Level - Low 

Low Low, Level 1

1, 2(f), 3(f)[2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [-152.5] 

inches

b. Drywell Pressure -

High

1, 2(f), 3(f)[2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [1.44] psig

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

[SR 3.3.5.1.4]

SR 3.3.5.1.6

 [117] 

seconds

d. Reactor Vessel 

Water Level - Low, 

Level 3 

(Confirmatory)

1, 2(f), 3(f)[1] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [10.8] inches

e. LPCS Pump 

Discharge Pressure 

- High

1, 2(f), 3(f)[2] G SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [125] psig 

and 

 [165] psig

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(c) 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.

(d) 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].

(f) With reactor steam dome pressure > [150] psig.
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-14 Rev. 4.0

Table 3.3.5.1-1 (page 7 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

4. ADS Trip System A

f. LPCI Pump A 

Discharge Pressure 

- High

1, 2(f), 3(f)[2] G SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

 [115] psig 

and 

 [135] psig

g. [ ADS Bypass Timer 

(High Drywell 

Pressure) ]

1, 2(f), 3(f)[2] G SR 3.3.5.1.2

[SR 3.3.5.1.4]

SR 3.3.5.1.6

 [9.4] minutes

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

5. ADS Trip System B

a. Reactor Vessel 

Water Level - Low 

Low Low, Level 1

1, 2(f), 3(f)[2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [-152.5] 

inches

b. Drywell Pressure -

High

1, 2(f), 3(f)[2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [1.44] psig

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

[SR 3.3.5.1.4]

SR 3.3.5.1.6

 [117] 

seconds

(c) 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.

(d) 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].

(f) With reactor steam dome pressure > [150] psig.
ECCS Instrumentation (Without Setpoint Control Program)

3.3.5.1A

General Electric BWR/6 STS 3.3.5.1A-15 Rev. 4.0

Table 3.3.5.1-1 (page 8 of 8)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

5. ADS Trip System B

d. Reactor Vessel 

Water Level -

Low, Level 3 

(Confirmatory)

1, 2(f), 3(f)[1] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3](c)(d)

SR 3.3.5.1.5(c)(d)

SR 3.3.5.1.6

 [10.8] inches

e. LPCI Pumps B & C 

Discharge Pressure 

- High

1, 2(f), 3(f)[4]

[2 per 

pump]

G SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

 [115] psig 

and

 [135] psig

f. [ADS Bypass Timer 

(High Drywell 

Pressure)]

1, 2(f), 3(f)[2] G SR 3.3.5.1.2

[SR 3.3.5.1.4]

SR 3.3.5.1.6

 [9.4] minutes

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

(c) 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.

(d) 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].

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

ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.5.1B Emergency Core Cooling System (ECCS) Instrumentation (With Setpoint Control 

Program)

LCO 3.3.5.1B 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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.5.1-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

B.1 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 1.a, 1.b, 2.a 

and 2.b.

-------------------------------------

Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable.

AND

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 3.a and 3.b.

-------------------------------------

Declare High Pressure 

Core Spray (HPCS) System 

inoperable.

AND

B.3 Place channel in trip.

1 hour from discovery 

of loss of HPCS 

initiation capability

24 hours

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

C.1 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 1.c, 1.d, 2.c, 

and 2.d.

-------------------------------------

Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable.

AND

C.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions

24 hours
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

D.1 ---------------NOTE--------------

Only applicable if HPCS 

pump suction is not aligned 

to the suppression pool.

-------------------------------------

Declare HPCS System 

inoperable.

AND

D.2.1 Place channel in trip.

 OR

D.2.2 Align the HPCS pump 

suction to the suppression 

pool.

1 hour from discovery 

of loss of HPCS 

initiation capability

24 hours

24 hours

E. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

E.1 --------------NOTES-------------

1. Only applicable in 

MODES 1, 2, and 3.

2. Only applicable for 

Functions 1.e, 1.f, and 

2.e.

-------------------------------------

Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable.

AND

E.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions

7 days
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-4 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

F.1 Declare Automatic 

Depressurization System 

(ADS) valves inoperable.

AND

F.2 Place channel in trip.

1 hour from discovery 

of loss of ADS 

initiation capability in 

both trip systems

96 hours from 

discovery of 

inoperable channel 

concurrent with 

HPCS or reactor core 

isolation cooling 

(RCIC) inoperable

AND

8 days

G. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1.

G.1 ---------------NOTE--------------

Only applicable for 

Functions 4.c, 4.e, 4.f, 4.g, 

5.c, 5.e, and 5.f.

-------------------------------------

Declare ADS valves 

inoperable.

AND

G.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of ADS 

initiation capability in 

both trip systems

96 hours from 

discovery of 

inoperable channel 

concurrent with 

HPCS or RCIC 

inoperable

AND

8 days
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-5 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

H. Required Action and 

associated Completion 

Time of Condition B, C, 

D, E, F, or G not met.

H.1 Declare associated 

supported feature(s) 

inoperable.

Immediately

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 hours for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours 

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 hours

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 ]
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.5.1.3 [ Calibrate the trip unit in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.5.1.4 [ Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.5.1.5 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [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 ]
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-7 Rev. 4.0

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 ]
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-8 Rev. 4.0

Table 3.3.5.1-1 (page 1 of 6)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

1. Low Pressure Coolant Injection-A (LPCI) 

and Low Pressure Core Spray (LPCS) 

Subsystems

a. Reactor Vessel Water Level - Low 

Low Low, Level 1

1, 2, 3, 

4

(a)

, 5

(a)

[2](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

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

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

c. LPCI Pump A Start - Time Delay 

Relay

1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.2

[SR 3.3.5.1.4]

SR 3.3.5.1.6

d. Reactor Steam Dome Pressure - Low 

(Injection Permissive)

1, 2, 3 [3] C SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

4

(a), 5(a) [3] B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

e. [ LPCS Pump Discharge Flow - Low 

(Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(b) Also required to initiate the associated [Technical Specifications (TS) required functions].
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-9 Rev. 4.0

Table 3.3.5.1-1 (page 2 of 6)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

1. LPCI and LPCS Subsystems

f. [ LPCI Pump A Discharge Flow - Low 

(Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

[ g. Manual Initiation 1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.6 ]

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel Water Level - Low 

Low Low, Level 1

1, 2, 3, 

4

(a)

, 5

(a)

[2](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

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

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

c. LPCI Pump B Start - Time Delay

Relay

1, 2, 3, 

4

(a) ,5(a)

[1] C SR 3.3.5.1.2

SR 3.3.5.1.4

SR 3.3.5.1.6

d. Reactor Steam Dome Pressure - Low 

(Injection Permissive)

1, 2, 3 [3] C SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(b) Also required to initiate the associated [TS required functions].
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-10 Rev. 4.0

Table 3.3.5.1-1 (page 3 of 6)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

2. LPCI B and LPCI C Subsystems

e. [ LPCI Pump B and LPCI Pump C 

Discharge Flow - Low (Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[2]

[1 per pump]

E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

[ f. Manual Initiation 1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.6 ]

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel Water Level - Low 

Low, Level 2

1, 2, 3, 

4

(a)

, 5

(a)

[4](b) B SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

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

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

SR 3.3.5.1.7

c. Reactor Vessel Water Level - High, 

Level 8

1, 2, 3, 

4

(a)

, 5

(a)

[2] C SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

d. Condensate Storage Tank Level - Low 1, 2, 3, 

4

(c)

, 5

(c)

[2] D SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(b) Also required to initiate the associated [TS required functions].

(c) When HPCS is OPERABLE for compliance with LCO 3.5.2, "ECCS - Shutdown," and aligned to the condensate 

storage tank while tank water level is not within the limit of SR 3.5.2.2.
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-11 Rev. 4.0

Table 3.3.5.1-1 (page 4 of 6)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

3. HPCS System

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

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

f. [ HPCS Pump Discharge Pressure -

High (Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

g. [ HPCS System Flow Rate - Low 

(Bypass) ]

1, 2, 3, 

4

(a)

, 5

(a)

[1] E SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

[ h. Manual Initiation 1, 2, 3, 

4

(a)

, 5

(a)

[1] C SR 3.3.5.1.6 ]

4. Automatic Depressurization System (ADS) 

Trip System A

a. Reactor Vessel Water Level - Low 

Low Low, Level 1

1, 2(d), 3(d) [2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

b. Drywell Pressure - High 1, 2(d), 3(d) [2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

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

[SR 3.3.5.1.4]

SR 3.3.5.1.6

(a) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, “ECCS - Shutdown.”

(d) With reactor steam dome pressure > [150] psig.
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-12 Rev. 4.0

Table 3.3.5.1-1 (page 5 of 6)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

4. ADS Trip System A 

d. Reactor Vessel Water Level - Low, 

Level 3 (Confirmatory)

1, 2(d), 3(d) [1] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

e. LPCS Pump Discharge Pressure -

High

1, 2(d), 3(d) [2] G SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

f. LPCI Pump A Discharge Pressure -

High

1, 2(d), 3(d) [2] G SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

g. [ ADS Bypass Timer (High Drywell 

Pressure) ]

1, 2(d), 3(d) [2] G SR 3.3.5.1.2

[SR 3.3.5.1.4]

SR 3.3.5.1.6

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

5. ADS Trip System B

a. Reactor Vessel Water Level - Low 

Low Low, Level 1

1, 2(d), 3(d) [2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

b. Drywell Pressure - High 1, 2(d), 3(d) [2] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

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

[SR 3.3.5.1.4]

SR 3.3.5.1.6

(d) With reactor steam dome pressure > [150] psig.
ECCS Instrumentation (With Setpoint Control Program)

3.3.5.1B

General Electric BWR/6 STS 3.3.5.1B-13 Rev. 4.0

Table 3.3.5.1-1 (page 6 of 6)

Emergency Core Cooling System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

5. ADS Trip System B

d. Reactor Vessel Water Level -

Low, Level 3 (Confirmatory)

1, 2(d), 3(d) [1] F SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

e. LPCI Pumps B & C Discharge 

Pressure - High

1, 2(d), 3(d) [4]

[2 per pump]

G SR 3.3.5.1.1

SR 3.3.5.1.2

[SR 3.3.5.1.3]

SR 3.3.5.1.5

SR 3.3.5.1.6

f. [ADS Bypass Timer (High Drywell 

Pressure)]

1, 2(d), 3

(d) [2] G SR 3.3.5.1.2

[SR 3.3.5.1.4]

SR 3.3.5.1.6

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

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

RCIC System Instrumentation (Without Setpoint Control Program)

3.3.5.2A

General Electric BWR/6 STS 3.3.5.2A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.5.2A Reactor Core Isolation Cooling (RCIC) System Instrumentation (Without Setpoint 

Control Program)

LCO 3.3.5.2A The RCIC System instrumentation for each Function in Table 3.3.5.2-1 

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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.5.2-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1.

B.1 Declare RCIC System 

inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of RCIC 

initiation capability

24 hours

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1.

C.1 Restore channel to 

OPERABLE status.

24 hours
RCIC System Instrumentation (Without Setpoint Control Program)

3.3.5.2A

General Electric BWR/6 STS 3.3.5.2A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1.

D.1 ---------------NOTE--------------

Only applicable if RCIC 

pump suction is not aligned 

to the suppression pool.

-------------------------------------

Declare RCIC System 

inoperable.

AND

D.2.1 Place channel in trip.

 OR

D.2.2 Align RCIC pump suction to 

the suppression pool.

1 hour from discovery 

of loss of RCIC 

initiation capability

24 hours

24 hours

E. Required Action and 

associated Completion 

Time of Condition B, C, 

or D not met.

E.1 Declare RCIC System 

inoperable.

Immediately
RCIC System Instrumentation (Without Setpoint Control Program)

3.3.5.2A

General Electric BWR/6 STS 3.3.5.2A-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.5.2-1 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 hours for Functions 2 and 5; and (b) for up to 6 hours for 

Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.5.2.1 Perform CHANNEL CHECK. [ 12 hours

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 ]

SR 3.3.5.2.3 [ Calibrate the trip units. [ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
RCIC System Instrumentation (Without Setpoint Control Program)

3.3.5.2A

General Electric BWR/6 STS 3.3.5.2A-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. [ 18 months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCIC System Instrumentation (Without Setpoint Control Program)

3.3.5.2A

General Electric BWR/6 STS 3.3.5.2A-5 Rev. 4.0

Table 3.3.5.2-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation

FUNCTION

REQUIRED 

CHANNELS PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Reactor Vessel Water 

Level - Low Low, Level 2

[4] B SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3](a)(b)

SR 3.3.5.2.4(a)(b)

SR 3.3.5.2.5

 [-43.8] inches

2. Reactor Vessel Water 

Level - High, Level 8

[2] C SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3](a)(b)

SR 3.3.5.2.4(a)(b)

SR 3.3.5.2.5

 [55.7] inches

3. Condensate Storage Tank 

Level - Low

[2] D SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3](a)(b)

SR 3.3.5.2.4(a)(b)

SR 3.3.5.2.5

 [-3] inches

[ 4. Suppression Pool Water 

Level - High

[2] D SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3](a)(b)

SR 3.3.5.2.4(a)(b)

SR 3.3.5.2.5

 [7.0] inches ]

[ 5. Manual Initiation [1] C SR 3.3.5.2.5 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].

RCIC System Instrumentation (With Setpoint Control Program)

3.3.5.2B

General Electric BWR/6 STS 3.3.5.2B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.5.2B Reactor Core Isolation Cooling (RCIC) System Instrumentation (With Setpoint 

Control Program)

LCO 3.3.5.2B The RCIC System instrumentation for each Function in Table 3.3.5.2-1 

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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.5.2-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1.

B.1 Declare RCIC System 

inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of RCIC 

initiation capability

24 hours

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1.

C.1 Restore channel to 

OPERABLE status.

24 hours
RCIC System Instrumentation (With Setpoint Control Program)

3.3.5.2B

General Electric BWR/6 STS 3.3.5.2B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1.

D.1 ---------------NOTE--------------

Only applicable if RCIC 

pump suction is not aligned 

to the suppression pool.

-------------------------------------

Declare RCIC System 

inoperable.

AND

D.2.1 Place channel in trip.

 OR

D.2.2 Align RCIC pump suction to 

the suppression pool.

1 hour from discovery 

of loss of RCIC 

initiation capability

24 hours

24 hours

E. Required Action and 

associated Completion 

Time of Condition B, C, 

or D not met.

E.1 Declare RCIC System 

inoperable.

Immediately
RCIC System Instrumentation (With Setpoint Control Program)

3.3.5.2B

General Electric BWR/6 STS 3.3.5.2B-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.5.2-1 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 hours for Functions 2 and 5; and (b) for up to 6 hours for 

Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.5.2.1 Perform CHANNEL CHECK. [ 12 hours

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 ]

SR 3.3.5.2.3 [ Calibrate the trip units in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
RCIC System Instrumentation (With Setpoint Control Program)

3.3.5.2B

General Electric BWR/6 STS 3.3.5.2B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.5.2.4 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 18 months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCIC System Instrumentation (With Setpoint Control Program)

3.3.5.2B

General Electric BWR/6 STS 3.3.5.2B-5 Rev. 4.0

Table 3.3.5.2-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation

FUNCTION

REQUIRED 

CHANNELS PER 

FUNCTION

CONDITIONS 

REFERENCED 

FROM REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

1. Reactor Vessel Water Level - Low Low, 

Level 2

[4] B SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3]

SR 3.3.5.2.4

SR 3.3.5.2.5

2. Reactor Vessel Water Level - High, Level 8 [2] C SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3]

SR 3.3.5.2.4

SR 3.3.5.2.5

3. Condensate Storage Tank Level - Low [2] D SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3]

SR 3.3.5.2.4

SR 3.3.5.2.5

[ 4. Suppression Pool Water Level - High [2] D SR 3.3.5.2.1

SR 3.3.5.2.2

[SR 3.3.5.2.3]

SR 3.3.5.2.4

SR 3.3.5.2.5 ]

[ 5. Manual Initiation [1] C SR 3.3.5.2.5 ]

Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.1A Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

LCO 3.3.6.1A 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 

channels inoperable.

A.1 Place channel in trip. 12 hours for 

Functions 2.b, 5.c, 

5.d, and 5.e

AND

24 hours for 

Functions other than 

Functions 2.b, 5.c, 

5.d, and 5.e

B. One or more automatic 

Functions with isolation 

capability not 

maintained.

B.1 Restore isolation capability. 1 hour

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1 Enter the Condition 

referenced in 

Table 3.3.6.1-1 for the 

channel.

Immediately
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

D.1 Isolate associated main 

steam line (MSL).

OR

D.2.1 Be in MODE 3.

 AND

D.2.2 Be in MODE 4.

12 hours

12 hours

36 hours

E. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

E.1 Be in MODE 2. 6 hours

F. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

F.1 Isolate the affected 

penetration flow path(s).

1 hour

G. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

G.1 Isolate the affected 

penetration flow path(s).

24 hours

H. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

OR

Required Action and 

associated Completion 

Time of Condition F or G 

not met.

H.1 Be in MODE 3.

AND

H.2 Be in MODE 4.

12 hours

36 hours
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

I. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

I.1 Declare associated standby 

liquid control subsystem 

inoperable.

OR

I.2 Isolate the Reactor Water 

Cleanup System.

1 hour

1 hour

J. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

J.1 Initiate action to restore 

channel to OPERABLE 

status.

OR

J.2 Initiate action to isolate the 

Residual Heat Removal 

(RHR) Shutdown Cooling 

System.

Immediately

Immediately

K. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

K.1 Isolate the affected 

penetration flow path(s).

OR

K.2.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

 AND

K.2.2 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel.

Immediately

Immediately

Immediately
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-4 Rev. 4.0

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 hours, provided the associated Function maintains isolation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.1.1 Perform CHANNEL CHECK. [ 12 hours

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 ] ]
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-5 Rev. 4.0

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 ]
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

----------------------------------REVIEWER’S 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 

is within limits.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-7 Rev. 4.0

Table 3.3.6.1-1 (page 1 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Main Steam Line Isolation

a. Reactor Vessel 

Water Level - Low 

Low Low, Level 1

1,2,3 [2] D SR 3.3.6.1.1

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

 [-152.5] 

inches

b. Main Steam Line 

Pressure - Low

1 [2] E SR 3.3.6.1.1

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

 [837] psig

c. Main Steam Line 

Flow - High

1,2,3 [2] per 

MSL

D SR 3.3.6.1.1

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

 [176.5] psig

d. Condenser Vacuum -

Low

1,2(a),

3

(a)

[2] D SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

 [8.7] inches

Hg vacuum

e. Main Steam Tunnel 

Temperature - High

1,2,3 [2] D SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [191]F

f. Main Steam Tunnel 

Differential 

Temperature - High

1,2,3 [2] D SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [104]F

[ g. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 NA ]

(a) With any turbine [stop valve] not closed.
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-8 Rev. 4.0

Table 3.3.6.1-1 (page 2 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

2. Primary Containment 

Isolation

a. Reactor Vessel 

Water Level - Low 

Low, Level 2

1,2,3 [2] H SR 3.3.6.1.1

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

 [-43.8] 

inches

b. Drywell Pressure -

High

1,2,3 [2] H SR 3.3.6.1.1

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

 [1.43] psig

[ c. Reactor Vessel 

Water Level - Low 

Low Low, Level 1 

(ECCS Divisions 1 

and 2)

1,2,3 [2] F SR 3.3.6.1.1

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

 [-152.5] 

inches ]

[ d. Drywell Pressure -

High (ECCS 

Divisions 1 and 2)

1,2,3 [2] F SR 3.3.6.1.1

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

 [1.44] psig ]

[ e. Reactor Vessel 

Water Level - Low 

Low, Level 2 (HPCS)

1,2,3 [4] F SR 3.3.6.1.1

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

 [-43.8] 

inches ]

[ f. Drywell Pressure -

High (HPCS)

1,2,3 [4] F SR 3.3.6.1.1

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

 [1.44] psig ]
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-9 Rev. 4.0

Table 3.3.6.1-1 (page 3 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

2. Primary Containment 

Isolation

g. Containment and 

Drywell Ventilation 

Exhaust RadiationHigh

1,2,3 [2] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

SR 3.3.6.1.7

 [4.0] mR/hr

[(b)] [2] K SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

SR 3.3.6.1.7

 [4.0] mR/hr

[ 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 

Flow - High

1,2,3 [1] F SR 3.3.6.1.1

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

 [64] inches 

water

[ b. RCIC Steam Line 

Flow Time Delay

[1,2,3] [1] F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

 [3] seconds 

and 

 [7] seconds ]

c. RCIC Steam Supply 

Line Pressure - Low

1,2,3 [1] F SR 3.3.6.1.1

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

 [53] psig

d. RCIC Turbine 

Exhaust Diaphragm 

Pressure - High

1,2,3 [2] F SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

 [20] psig

[(b) During movement of [recently] irradiated fuel assemblies in [primary or secondary containment], or operations 

with a potential for draining the reactor vessel.]
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-10 Rev. 4.0

Table 3.3.6.1-1 (page 4 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

3. RCIC System Isolation

e. RCIC Equipment 

Room Ambient 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [191]F

f. RCIC Equipment 

Room Differential 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [128]F

g. Main Steam Line 

Tunnel Ambient 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [191]F

h. Main Steam Line 

Tunnel Differential 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [104]F

i. Main Steam Line 

Tunnel Temperature 

Timer

1,2,3 [1] F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

 [30] minutes

j. RHR Equipment 

Room Ambient 

Temperature - High

1,2,3 [1 per 

room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [171]F

k. RHR Equipment 

Room Differential 

Temperature - High

1,2,3 [1 per 

room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [102]F

l. RCIC/RHR Steam 

Line Flow - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

 [43] inches 

water

m. Drywell Pressure -

High

1,2,3 [1] F SR 3.3.6.1.1

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

 [1.44] psig
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-11 Rev. 4.0

Table 3.3.6.1-1 (page 5 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

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 -

High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

[SR 3.3.6.1.7]

 [89] gpm

b. Differential Flow -

Timer

1,2,3 [1] F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

 [57] seconds

c. RWCU Heat 

Exchanger 

Equipment Room 

Temperature-High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [126]F

d. RWCU Heat 

Exchanger 

Equipment Room 

Differential 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [66]F

e. RWCU Pump Rooms 

Temperature - High

1,2,3 [1]

[1 per 

room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [176]F

f. RWCU Pump Rooms 

Differential 

Temperature - High

1,2,3 [1]

[1 per 

room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [118]F

g. RWCU Valve Nest 

Room Temperature -

High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [141]F

h. RWCU Valve Nest 

Room Differential 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [73]F
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-12 Rev. 4.0

Table 3.3.6.1-1 (page 6 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

4. RWCU System Isolation

i. Main Steam Line 

Tunnel Ambient 

Temperature – High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [191]F

j. Main Steam Line 

Tunnel Differential 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [104]F

k. Reactor Vessel 

Water Level - Low 

Low, Level 2

1,2,3 [2] F SR 3.3.6.1.1

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

 [-43.8] 

inches

l. Standby Liquid 

Control System 

Initiation

1,2 [1] I SR 3.3.6.1.6 NA

[ m. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 NA ]

5. Shutdown Cooling 

System Isolation

a. RHR Equipment 

Room Ambient 

Temperature - High

2,3 [1 per 

room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [171]F

b. RHR Equipment 

Room Differential 

Temperature - High

2,3 [1 per 

room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

 [102]F

c. Reactor Vessel 

Water Level - Low, 

Level 3

3,4,5 [2](c) J SR 3.3.6.1.1

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

 [10.8] inches

(c) Only one trip system required in MODES 4 and 5 with RHR Shutdown Cooling System integrity maintained.
Primary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.1A

General Electric BWR/6 STS 3.3.6.1A-13 Rev. 4.0

Table 3.3.6.1-1 (page 7 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

5. Shutdown Cooling 

System Isolation

d. Reactor Steam Dome 

Pressure - High

1,2,3 [2] F SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

 [150] psig

e. Drywell Pressure -

High

1,2,3 [2] F SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

 [1.43] psig

Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.1B Primary Containment Isolation Instrumentation (With Setpoint Control Program)

LCO 3.3.6.1B 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 

channels inoperable.

A.1 Place channel in trip. 12 hours for 

Functions 2.b, 5.c, 

5.d, and 5.e

AND

24 hours for 

Functions other than 

Functions 2.b, 5.c, 

5.d, and 5.e

B. One or more automatic 

Functions with isolation 

capability not 

maintained.

B.1 Restore isolation capability. 1 hour

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1 Enter the Condition 

referenced in 

Table 3.3.6.1-1 for the 

channel.

Immediately
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

D.1 Isolate associated main 

steam line (MSL).

OR

D.2.1 Be in MODE 3.

 AND

D.2.2 Be in MODE 4.

12 hours

12 hours

36 hours

E. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

E.1 Be in MODE 2. 6 hours

F. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

F.1 Isolate the affected 

penetration flow path(s).

1 hour

G. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

G.1 Isolate the affected 

penetration flow path(s).

24 hours

H. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

OR

Required Action and 

associated Completion 

Time of Condition F or G 

not met.

H.1 Be in MODE 3.

AND

H.2 Be in MODE 4.

12 hours

36 hours
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

I. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

I.1 Declare associated standby 

liquid control subsystem 

inoperable.

OR

I.2 Isolate the Reactor Water 

Cleanup System.

1 hour

1 hour

J. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

J.1 Initiate action to restore 

channel to OPERABLE 

status.

OR

J.2 Initiate action to isolate the 

Residual Heat Removal 

(RHR) Shutdown Cooling 

System.

Immediately

Immediately

K. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

K.1 Isolate the affected 

penetration flow path(s).

OR

K.2.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

 AND

K.2.2 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel.

Immediately

Immediately

Immediately
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-4 Rev. 4.0

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 hours, provided the associated Function maintains isolation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.1.1 Perform CHANNEL CHECK. [ 12 hours

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 in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.6.1.4 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.6.1.5 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [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 ]
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

----------------------------------REVIEWER’S 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 

is within limits.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-7 Rev. 4.0

Table 3.3.6.1-1 (page 1 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

1. Main Steam Line Isolation

a. Reactor Vessel Water Level -

Low Low Low, Level 1

1,2,3 [2] D SR 3.3.6.1.1

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

b. Main Steam Line Pressure - Low 1 [2] E SR 3.3.6.1.1

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 Flow - High 1,2,3 [2] per MSL D SR 3.3.6.1.1

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 - Low 1,2(a),

3

(a)

[2] D SR 3.3.6.1.1

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. Main Steam Tunnel Temperature 

- High

1,2,3 [2] D SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

f. Main Steam Tunnel Differential 

Temperature - High

1,2,3 [2] D SR 3.3.6.1.1

SR 3.3.6.1.2

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 ]

(a) With any turbine [stop valve] not closed.
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-8 Rev. 4.0

Table 3.3.6.1-1 (page 2 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

2. Primary Containment Isolation

a. Reactor Vessel Water Level -

Low Low, Level 2

1,2,3 [2] H SR 3.3.6.1.1

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

b. Drywell Pressure - High 1,2,3 [2] H SR 3.3.6.1.1

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 Water Level -

Low Low Low, Level 1 (ECCS 

Divisions 1 and 2)

1,2,3 [2] F SR 3.3.6.1.1

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. Drywell Pressure - High (ECCS 

Divisions 1 and 2)

1,2,3 [2] F SR 3.3.6.1.1

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 ]

[ e. Reactor Vessel Water Level -

Low Low, Level 2 (HPCS)

1,2,3 [4] F SR 3.3.6.1.1

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 ]

[ f. Drywell Pressure - High (HPCS) 1,2,3 [4] F SR 3.3.6.1.1

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 ]
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-9 Rev. 4.0

Table 3.3.6.1-1 (page 3 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

2. Primary Containment Isolation

g. Containment and Drywell 

Ventilation Exhaust RadiationHigh

1,2,3 [2] F SR 3.3.6.1.1

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)] [2] K SR 3.3.6.1.1

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 ]

3. Reactor Core Isolation Cooling (RCIC) 

System Isolation

a. RCIC Steam Line Flow - High 1,2,3 [1] F SR 3.3.6.1.1

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

[ b. RCIC Steam Line Flow Time 

Delay

[1,2,3] [1] F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6 ]

c. RCIC Steam Supply Line 

Pressure - Low

1,2,3 [1] F SR 3.3.6.1.1

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 Exhaust 

Diaphragm Pressure - High

1,2,3 [2] F SR 3.3.6.1.1

SR 3.3.6.1.2

[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], or operations 

with a potential for draining the reactor vessel.]
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-10 Rev. 4.0

Table 3.3.6.1-1 (page 4 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

3. RCIC System Isolation

e. RCIC Equipment Room Ambient 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

f. RCIC Equipment Room 

Differential Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

g. Main Steam Line Tunnel Ambient 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

h. Main Steam Line Tunnel 

Differential Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

i. Main Steam Line Tunnel 

Temperature Timer

1,2,3 [1] F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

j. RHR Equipment Room Ambient 

Temperature - High

1,2,3 [1 per room] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

k. RHR Equipment Room 

Differential Temperature - High

1,2,3 [1 per room] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

l. RCIC/RHR Steam Line Flow -

High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

m. Drywell Pressure - High 1,2,3 [1] F SR 3.3.6.1.1

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
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-11 Rev. 4.0

Table 3.3.6.1-1 (page 5 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

3. RCIC System Isolation

[ n. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 ]

4. Reactor Water Cleanup (RWCU) 

System Isolation

a. Differential Flow - High 1,2,3 [1] F SR 3.3.6.1.1

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 - Timer 1,2,3 [1] F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

c. RWCU Heat Exchanger 

Equipment Room TemperatureHigh

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

d. RWCU Heat Exchanger 

Equipment Room Differential 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

e. RWCU Pump Rooms 

Temperature - High

1,2,3 [1]

[1 per room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

f. RWCU Pump Rooms Differential 

Temperature - High

1,2,3 [1]

[1 per room]

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

g. RWCU Valve Nest Room 

Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

h. RWCU Valve Nest Room 

Differential Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-12 Rev. 4.0

Table 3.3.6.1-1 (page 6 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

4. RWCU System Isolation

i. Main Steam Line Tunnel Ambient 

Temperature – High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

j. Main Steam Line Tunnel 

Differential Temperature - High

1,2,3 [1] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

k. Reactor Vessel Water Level -

Low Low, Level 2

1,2,3 [2] F SR 3.3.6.1.1

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

l. Standby Liquid Control System 

Initiation

1,2 [1] I SR 3.3.6.1.6

[ m. Manual Initiation 1,2,3 [2] G SR 3.3.6.1.6 ]

5. Shutdown Cooling System Isolation

a. RHR Equipment Room Ambient 

Temperature - High

2,3 [1 per room] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

b. RHR Equipment Room 

Differential Temperature - High

2,3 [1 per room] F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.5

SR 3.3.6.1.6

c. Reactor Vessel Water Level -

Low, Level 3

3,4,5 [2](c) J SR 3.3.6.1.1

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) Only one trip system required in MODES 4 and 5 with RHR Shutdown Cooling System integrity maintained.
Primary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.1B

General Electric BWR/6 STS 3.3.6.1B-13 Rev. 4.0

Table 3.3.6.1-1 (page 7 of 7)

Primary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION C.1

SURVEILLANCE

REQUIREMENTS

5. Shutdown Cooling System Isolation

d. Reactor Steam Dome Pressure -

High

1,2,3 [2] F SR 3.3.6.1.1

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 - High 1,2,3 [2] F SR 3.3.6.1.1

SR 3.3.6.1.2

[SR 3.3.6.1.3]

SR 3.3.6.1.5

SR 3.3.6.1.6

Secondary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.2A

General Electric BWR/6 STS 3.3.6.2A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.2A Secondary Containment Isolation Instrumentation (Without Setpoint Control 

Program)

LCO 3.3.6.2A 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 

inoperable.

A.1 Place channel in trip. 12 hours for 

Function 2

AND

24 hours for 

Functions other than 

Function 2

B. One or more automatic 

Functions with 

secondary containment 

isolation capability not 

maintained.

B.1 Restore secondary 

containment isolation 

capability.

1 hour

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1.1 Isolate the associated 

penetration flow path(s).

 OR

C.1.2 Declare associated 

secondary containment 

isolation valves inoperable.

AND

1 hour

1 hour
Secondary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.2A

General Electric BWR/6 STS 3.3.6.2A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2.1 Place the associated 

standby gas treatment 

(SGT) subsystem(s) in 

operation.

 OR

C.2.2 Declare associated SGT 

subsystem inoperable.

1 hour

1 hour

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 hours, provided the associated Function maintains secondary containment isolation 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.2.1 Perform CHANNEL CHECK. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Secondary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.2A

General Electric BWR/6 STS 3.3.6.2A-3 Rev. 4.0

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 ]
Secondary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.2A

General Electric BWR/6 STS 3.3.6.2A-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

----------------------------------REVIEWER’S 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 

is within limits.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Secondary Containment Isolation Instrumentation (Without Setpoint Control Program)

3.3.6.2A

General Electric BWR/6 STS 3.3.6.2A-5 Rev. 4.0

Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation

FUNCTION

APPLICABLE 

MODES AND 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS

PER TRIP

SYSTEM

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Reactor Vessel Water 

Level - Low Low, Level 2

1,2,3,[(a)] [2] SR 3.3.6.2.1

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

 [-43.8] inches

2. Drywell Pressure - High 1,2,3 [2] SR 3.3.6.2.1

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

 [1.43] psig

3. Fuel Handling Area 

Ventilation Exhaust 

Radiation - High High

1,2,3,[(a),(b)] [2] SR 3.3.6.2.1

SR 3.3.6.2.2

SR 3.3.6.2.4

SR 3.3.6.2.5

SR 3.3.6.2.6

 [4.0] mR/hr

4. Fuel Handling Area Pool 

Sweep Exhaust Radiation 

- High High

1,2,3,[(a),(b)] [2] SR 3.3.6.2.1

SR 3.3.6.2.2

SR 3.3.6.2.4

SR 3.3.6.2.5

SR 3.3.6.2.6

 [35] mR/hr

5. [ Manual Initiation 1,2,3,[(a),(b)] [1 per group] SR 3.3.6.2.5 NA ]

(a) During operations with a potential for draining the reactor vessel.

(b) During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

Secondary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.2B

General Electric BWR/6 STS 3.3.6.2B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.2B Secondary Containment Isolation Instrumentation (With Setpoint Control Program)

LCO 3.3.6.2B 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 

inoperable.

A.1 Place channel in trip. 12 hours for 

Function 2

AND

24 hours for 

Functions other than 

Function 2

B. One or more automatic 

Functions with 

secondary containment 

isolation capability not 

maintained.

B.1 Restore secondary 

containment isolation 

capability.

1 hour

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1.1 Isolate the associated 

penetration flow path(s).

 OR

C.1.2 Declare associated 

secondary containment 

isolation valves inoperable.

AND

1 hour

1 hour
Secondary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.2B

General Electric BWR/6 STS 3.3.6.2B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2.1 Place the associated 

standby gas treatment 

(SGT) subsystem(s) in 

operation.

 OR

C.2.2 Declare associated SGT 

subsystem inoperable.

1 hour

1 hour

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 hours, provided the associated Function maintains secondary containment isolation 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.2.1 Perform CHANNEL CHECK. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Secondary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.2B

General Electric BWR/6 STS 3.3.6.2B-3 Rev. 4.0

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 in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.6.2.4 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [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 ]
Secondary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.2B

General Electric BWR/6 STS 3.3.6.2B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

----------------------------------REVIEWER’S 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 

is within limits.

[ [18] months on a 

STAGGERED 

TEST BASIS

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Secondary Containment Isolation Instrumentation (With Setpoint Control Program)

3.3.6.2B

General Electric BWR/6 STS 3.3.6.2B-5 Rev. 4.0

Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation

FUNCTION

APPLICABLE 

MODES AND 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS

PER TRIP

SYSTEM

SURVEILLANCE

REQUIREMENTS

1. Reactor Vessel Water Level - Low Low, Level 2 1,2,3,[(a)] [2] SR 3.3.6.2.1

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

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 Ventilation Exhaust Radiation -

High High

1,2,3,[(a),(b)] [2] SR 3.3.6.2.1

SR 3.3.6.2.2

SR 3.3.6.2.4

SR 3.3.6.2.5

SR 3.3.6.2.6

4. Fuel Handling Area Pool Sweep Exhaust Radiation -

High High

1,2,3,[(a),(b)] [2] SR 3.3.6.2.1

SR 3.3.6.2.2

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),(b)] [1 per group] SR 3.3.6.2.5 ]

(a) During operations with a potential for draining the reactor vessel.

(b) During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment].

RHR Containment Spray System Instrumentation (Without Setpoint Control Program)

3.3.6.3A

General Electric BWR/6 STS 3.3.6.3A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.3A Residual Heat Removal (RHR) Containment Spray System Instrumentation (Without 

Setpoint Control Program)

LCO 3.3.6.3A 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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.6.3-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.3-1.

B.1 Declare associated RHR 

containment spray 

subsystem inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of RHR 

containment spray 

initiation capability in 

both trip systems

24 hours
RHR Containment Spray System Instrumentation (Without Setpoint Control Program)

3.3.6.3A

General Electric BWR/6 STS 3.3.6.3A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.3-1.

C.1 ---------------NOTE--------------

Only applicable for 

Functions 2 and 4.

-------------------------------------

Declare associated RHR 

containment spray 

subsystem inoperable.

AND

C.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of RHR 

containment spray 

initiation capability in 

both trip systems

24 hours

D. Required Action and 

associated Completion 

Time of Condition B or C 

not met.

D.1 Declare associated RHR 

containment spray 

subsystem inoperable.

Immediately
RHR Containment Spray System Instrumentation (Without Setpoint Control Program)

3.3.6.3A

General Electric BWR/6 STS 3.3.6.3A-3 Rev. 4.0

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 hours, provided the associated Function maintains RHR containment spray initiation 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.3.1 Perform CHANNEL CHECK. [ 12 hours

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 ]
RHR Containment Spray System Instrumentation (Without Setpoint Control Program)

3.3.6.3A

General Electric BWR/6 STS 3.3.6.3A-4 Rev. 4.0

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 ]
RHR Containment Spray System Instrumentation (Without Setpoint Control Program)

3.3.6.3A

General Electric BWR/6 STS 3.3.6.3A-5 Rev. 4.0

Table 3.3.6.3-1 (page 1 of 1)

RHR Containment Spray System Instrumentation

FUNCTION

REQUIRED

CHANNELS

PER TRIP

SYSTEM

CONDITIONS 

REFERENCED 

FROM

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Drywell Pressure - High [2] B SR 3.3.6.3.1

SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5

SR 3.3.6.3.6

 [1.44] psig

2. Containment Pressure - High [1] C SR 3.3.6.3.1

SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5

SR 3.3.6.3.6

 [8.34] psig

3. Reactor Vessel Water Level - Low 

Low Low, Level 1

[2] B SR 3.3.6.3.1

SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5

SR 3.3.6.3.6

 [-152.5] inches

4. System A and System B Timers [1] C SR 3.3.6.3.2

[SR 3.3.6.3.4]

SR 3.3.6.3.6

 [10.26] minutes 

and  [11.44] 

minutes

5. [ Manual Initiation [1] C SR 3.3.6.3.6 NA ]

RHR Containment Spray System Instrumentation (With Setpoint Control Program)

3.3.6.3B

General Electric BWR/6 STS 3.3.6.3B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.3B Residual Heat Removal (RHR) Containment Spray System Instrumentation (With 

Setpoint Control Program)

LCO 3.3.6.3B 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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.6.3-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.3-1.

B.1 Declare associated RHR 

containment spray 

subsystem inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of RHR 

containment spray 

initiation capability in 

both trip systems

24 hours
RHR Containment Spray System Instrumentation (With Setpoint Control Program)

3.3.6.3B

General Electric BWR/6 STS 3.3.6.3B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.3-1.

C.1 ---------------NOTE--------------

Only applicable for 

Functions 2 and 4.

-------------------------------------

Declare associated RHR 

containment spray 

subsystem inoperable.

AND

C.2 Restore channel to 

OPERABLE status.

1 hour from discovery 

of loss of RHR 

containment spray 

initiation capability in 

both trip systems

24 hours

D. Required Action and 

associated Completion 

Time of Condition B or C 

not met.

D.1 Declare associated RHR 

containment spray 

subsystem inoperable.

Immediately
RHR Containment Spray System Instrumentation (With Setpoint Control Program)

3.3.6.3B

General Electric BWR/6 STS 3.3.6.3B-3 Rev. 4.0

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 hours, provided the associated Function maintains RHR containment spray initiation 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.3.1 Perform CHANNEL CHECK. [ 12 hours

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 ]
RHR Containment Spray System Instrumentation (With Setpoint Control Program)

3.3.6.3B

General Electric BWR/6 STS 3.3.6.3B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.6.3.3 [ Calibrate the trip unit in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.6.3.4 [ Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.6.3.5 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [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 ]
RHR Containment Spray System Instrumentation (With Setpoint Control Program)

3.3.6.3B

General Electric BWR/6 STS 3.3.6.3B-5 Rev. 4.0

Table 3.3.6.3-1 (page 1 of 1)

RHR Containment Spray System Instrumentation

FUNCTION

REQUIRED

CHANNELS

PER TRIP

SYSTEM

CONDITIONS 

REFERENCED 

FROM

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

1. Drywell Pressure - High [2] B SR 3.3.6.3.1

SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5

SR 3.3.6.3.6

2. Containment Pressure - High [1] C SR 3.3.6.3.1

SR 3.3.6.3.2

[SR 3.3.6.3.3]

SR 3.3.6.3.5

SR 3.3.6.3.6

3. Reactor Vessel Water Level - Low Low Low, 

Level 1

[2] B SR 3.3.6.3.1

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

[SR 3.3.6.3.4]

SR 3.3.6.3.6

5. [ Manual Initiation [1] C SR 3.3.6.3.6 ]

SPMU System Instrumentation (Without Setpoint Control Program)

3.3.6.4A

General Electric BWR/6 STS 3.3.6.4A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.4A Suppression Pool Makeup (SPMU) System Instrumentation (Without Setpoint 

Control Program)

LCO 3.3.6.4A 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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.6.4-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.4-1.

B.1 Declare associated SPMU 

subsystem inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of SPMU 

initiation capability in 

both trip systems

24 hours

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.4-1.

C.1 ---------------NOTE--------------

Only applicable for 

Functions 3 and 6.

-------------------------------------

Declare associated SPMU 

subsystem inoperable.

AND

1 hour from discovery 

of loss of SPMU 

initiation capability in 

both trip systems
SPMU System Instrumentation (Without Setpoint Control Program)

3.3.6.4A

General Electric BWR/6 STS 3.3.6.4A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2 Restore channel to 

OPERABLE status.

24 hours

D. Required Action and 

associated Completion 

Time of Condition B or C 

not met.

D.1 Declare associated SPMU 

subsystem inoperable.

Immediately

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 hours, provided the associated Function maintains SPMU initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.4.1 Perform CHANNEL CHECK. [ 12 hours

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 ]
SPMU System Instrumentation (Without Setpoint Control Program)

3.3.6.4A

General Electric BWR/6 STS 3.3.6.4A-3 Rev. 4.0

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 ]
SPMU System Instrumentation (Without Setpoint Control Program)

3.3.6.4A

General Electric BWR/6 STS 3.3.6.4A-4 Rev. 4.0

Table 3.3.6.4-1 (page 1 of 1)

Suppression Pool Makeup System Instrumentation

FUNCTION

REQUIRED 

CHANNELS

PER

TRIP

SYSTEM

CONDITIONS 

REFERENCED 

FROM

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Drywell Pressure - High [2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

 [1.44] psig

2. Reactor Vessel Water Level - Low 

Low Low, Level 1

[2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

 [-152.5] inches

3. Suppression Pool Water Level -

Low Low

[1] C SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

 [17 ft 2 inches]

4. Drywell Pressure - High [2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

 [1.43] psig

5. Reactor Vessel Water Level - Low 

Low, Level 2

[2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

 [-43.8] inches

6. Timer [1] C SR 3.3.6.4.2

[SR 3.3.6.4.4]

SR 3.3.6.4.6

 [29.5] minutes

7. [ Manual Initiation [2] C SR 3.3.6.4.6 NA ]
SPMU System Instrumentation (With Setpoint Control Program)

3.3.6.4B

General Electric BWR/6 STS 3.3.6.4B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.6.4B Suppression Pool Makeup (SPMU) System Instrumentation (With Setpoint Control 

Program)

LCO 3.3.6.4B 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 

inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.6.4-1 for the 

channel.

Immediately

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.4-1.

B.1 Declare associated SPMU 

subsystem inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of SPMU 

initiation capability in 

both trip systems

24 hours

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.6.4-1.

C.1 ---------------NOTE--------------

Only applicable for 

Functions 3 and 6.

-------------------------------------

Declare associated SPMU 

subsystem inoperable.

AND

1 hour from discovery 

of loss of SPMU 

initiation capability in 

both trip systems
SPMU System Instrumentation (With Setpoint Control Program)

3.3.6.4B

General Electric BWR/6 STS 3.3.6.4B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2 Restore channel to 

OPERABLE status.

24 hours

D. Required Action and 

associated Completion 

Time of Condition B or C 

not met.

D.1 Declare associated SPMU 

subsystem inoperable.

Immediately

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 hours, provided the associated Function maintains SPMU initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.4.1 Perform CHANNEL CHECK. [ 12 hours

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 ]
SPMU System Instrumentation (With Setpoint Control Program)

3.3.6.4B

General Electric BWR/6 STS 3.3.6.4B-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.6.4.3 [ Calibrate the trip unit in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.6.4.4 [ Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.6.4.5 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [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 ]
SPMU System Instrumentation (With Setpoint Control Program)

3.3.6.4B

General Electric BWR/6 STS 3.3.6.4B-4 Rev. 4.0

Table 3.3.6.4-1 (page 1 of 1)

Suppression Pool Makeup System Instrumentation

FUNCTION

REQUIRED 

CHANNELS

PER

TRIP

SYSTEM

CONDITIONS 

REFERENCED 

FROM

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

1. Drywell Pressure - High [2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

2. Reactor Vessel Water Level - Low Low Low, Level 1 [2] B SR 3.3.6.4.1

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 - Low Low [1] C SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

4. Drywell Pressure - High [2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

5. Reactor Vessel Water Level - Low Low, Level 2 [2] B SR 3.3.6.4.1

SR 3.3.6.4.2

[SR 3.3.6.4.3]

SR 3.3.6.4.5

SR 3.3.6.4.6

6. Timer [1] C SR 3.3.6.4.2

[SR 3.3.6.4.4]

SR 3.3.6.4.6

7. [ Manual Initiation [2] C SR 3.3.6.4.6 ]
Relief and LLS Instrumentation (Without Setpoint Control Program)

3.3.6.5A

General Electric BWR/6 STS 3.3.6.5A-1 Rev. 4.0,

3.3 INSTRUMENTATION

3.3.6.5A Relief and Low-Low Set (LLS) Instrumentation (Without Setpoint Control Program)

LCO 3.3.6.5A 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 

inoperable.

A.1 Restore trip system to 

OPERABLE status.

7 days

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

OR

Two trip systems 

inoperable.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours
Relief and LLS Instrumentation (Without Setpoint Control Program)

3.3.6.5A

General Electric BWR/6 STS 3.3.6.5A-2 Rev. 4.0,

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 hours, 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 ]
Relief and LLS Instrumentation (Without Setpoint Control Program)

3.3.6.5A

General Electric BWR/6 STS 3.3.6.5A-3 Rev. 4.0,

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 asleft 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 ] ]
Relief and LLS Instrumentation (Without Setpoint Control Program)

3.3.6.5A

General Electric BWR/6 STS 3.3.6.5A-4 Rev. 4.0,

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 asleft 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 

Values shall be:

a. Relief Function

Low: [1103 ± 15 psig]

Medium: [1113 ± 15 psig]

High: [1123 ± 15 psig]

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]

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Relief and LLS Instrumentation (Without Setpoint Control Program)

3.3.6.5A

General Electric BWR/6 STS 3.3.6.5A-5 Rev. 4.0,

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 ]

Relief and LLS Instrumentation (With Setpoint Control Program)

3.3.6.5B

General Electric BWR/6 STS 3.3.6.5B-1 Rev. 4

3.3 INSTRUMENTATION

3.3.6.5B Relief and Low-Low Set (LLS) Instrumentation (With Setpoint Control Program)

LCO 3.3.6.5B 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 

inoperable.

A.1 Restore trip system to 

OPERABLE status.

7 days

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

OR

Two trip systems 

inoperable.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours
Relief and LLS Instrumentation (With Setpoint Control Program)

3.3.6.5B

General Electric BWR/6 STS 3.3.6.5B-2 Rev. 4

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 hours, 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 ]

SR 3.3.6.5.2 [ Calibrate the trip unit in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.3.6.5.3 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program. 

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Relief and LLS Instrumentation (With Setpoint Control Program)

3.3.6.5B

General Electric BWR/6 STS 3.3.6.5B-3 Rev. 4

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 ]

[CRFA] System Instrumentation (Without Setpoint Control Program)

3.3.7.1A

General Electric BWR/6 STS 3.3.7.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.7.1A [Control Room Fresh Air (CRFA)] System Instrumentation (Without Setpoint Control 

Program)

LCO 3.3.7.1A 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 

channels inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.7.1-1 for the 

channel.

Immediately

B. [ As required by 

Required Action A.1 and 

referenced in 

Table 3.3.7.1-1.

B.1 Declare associated [CRFA] 

subsystem inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of [CRFA] 

initiation capability in 

both trip systems

24 hours ]

C. [ As required by 

Required Action A.1 and 

referenced in 

Table 3.3.7.1-1.

C.1 Declare associated [CRFA] 

subsystem inoperable.

AND

C.2 Place channel in trip.

1 hour from discovery 

of loss of [CRFA] 

initiation capability in 

both trip systems

12 hours ]
[CRFA] System Instrumentation (Without Setpoint Control Program)

3.3.7.1A

General Electric BWR/6 STS 3.3.7.1A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.7.1-1.

D.1 Declare associated [CRFA] 

subsystem inoperable.

AND

D.2 Place channel in trip.

1 hour from discovery 

of loss of [CRFA] 

initiation capability in 

both trip systems

6 hours

E. Required Action and 

associated Completion 

Time of Condition B, C, 

or D not met.

E.1 ---------------NOTE--------------

Place in toxic gas 

protection mode if 

automatic transfer to toxic 

gas protection mode is 

inoperable.

-------------------------------------

Place the associated 

[CRFA] subsystem in the 

[isolation] mode of 

operation.

OR

E.2 Declare associated [CRFA] 

subsystem inoperable.

1 hour

1 hour
[CRFA] System Instrumentation (Without Setpoint Control Program)

3.3.7.1A

General Electric BWR/6 STS 3.3.7.1A-3 Rev. 4.0

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 hours provided the associated Function maintains [CRFA] initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.7.1.1 Perform CHANNEL CHECK. [ 12 hours

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 ] ]
[CRFA] System Instrumentation (Without Setpoint Control Program)

3.3.7.1A

General Electric BWR/6 STS 3.3.7.1A-4 Rev. 4.0

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 ]
[CRFA] System Instrumentation (Without Setpoint Control Program)

3.3.7.1A

General Electric BWR/6 STS 3.3.7.1A-5 Rev. 4.0

Table 3.3.7.1-1 (page 1 of 1)

[Control Room Fresh Air] System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Reactor Vessel Water 

Level - Low Low, Level 2

1, 2, 3, [(a)] [2] B SR 3.3.7.1.1

SR 3.3.7.1.2

[SR 3.3.7.1.3]

SR 3.3.7.1.4

SR 3.3.7.1.5

 [-43.8] inches

2. Drywell Pressure - High 1, 2, 3 [2] C SR 3.3.7.1.1

SR 3.3.7.1.2

[SR 3.3.7.1.3]

SR 3.3.7.1.4

SR 3.3.7.1.5

 [1.43] psig 

3. Control Room Ventilation 

Radiation Monitors

1, 2, 3, (a), 

(b)

[2] D SR 3.3.7.1.1

SR 3.3.7.1.2

SR 3.3.7.1.4

SR 3.3.7.1.5

 [5] mR/hr

(a) During operations with a potential for draining the reactor vessel.

(b) During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment]

[CRFA] System Instrumentation (With Setpoint Control Program)

3.3.7.1B

General Electric BWR/6 STS 3.3.7.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.7.1B [Control Room Fresh Air (CRFA)] System Instrumentation (With Setpoint Control 

Program)

LCO 3.3.7.1B 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 

channels inoperable.

A.1 Enter the Condition 

referenced in 

Table 3.3.7.1-1 for the 

channel.

Immediately

B. [ As required by 

Required Action A.1 and 

referenced in 

Table 3.3.7.1-1.

B.1 Declare associated [CRFA] 

subsystem inoperable.

AND

B.2 Place channel in trip.

1 hour from discovery 

of loss of [CRFA] 

initiation capability in 

both trip systems

24 hours ]

C. [ As required by 

Required Action A.1 and 

referenced in 

Table 3.3.7.1-1.

C.1 Declare associated [CRFA] 

subsystem inoperable.

AND

C.2 Place channel in trip.

1 hour from discovery 

of loss of [CRFA] 

initiation capability in 

both trip systems

12 hours ]
[CRFA] System Instrumentation (With Setpoint Control Program)

3.3.7.1B

General Electric BWR/6 STS 3.3.7.1B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.7.1-1.

D.1 Declare associated [CRFA] 

subsystem inoperable.

AND

D.2 Place channel in trip.

1 hour from discovery 

of loss of [CRFA] 

initiation capability in 

both trip systems

6 hours

E. Required Action and 

associated Completion 

Time of Condition B, C, 

or D not met.

E.1 ---------------NOTE--------------

Place in toxic gas 

protection mode if 

automatic transfer to toxic 

gas protection mode is 

inoperable.

-------------------------------------

Place the associated 

[CRFA] subsystem in the 

[isolation] mode of 

operation.

OR

E.2 Declare associated [CRFA] 

subsystem inoperable.

1 hour

1 hour
[CRFA] System Instrumentation (With Setpoint Control Program)

3.3.7.1B

General Electric BWR/6 STS 3.3.7.1B-3 Rev. 4.0

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 hours provided the associated Function maintains [CRFA] initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.7.1.1 Perform CHANNEL CHECK. [ 12 hours

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 in accordance with the 

Setpoint Control Program.

[ [92] days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
[CRFA] System Instrumentation (With Setpoint Control Program)

3.3.7.1B

General Electric BWR/6 STS 3.3.7.1B-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.7.1.4 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program.

[ [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 ]
[CRFA] System Instrumentation (With Setpoint Control Program)

3.3.7.1B

General Electric BWR/6 STS 3.3.7.1B-5 Rev. 4.0

Table 3.3.7.1-1 (page 1 of 1)

[Control Room Fresh Air] System Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS PER 

TRIP SYSTEM

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1

SURVEILLANCE

REQUIREMENTS

1. Reactor Vessel Water Level - Low 

Low, Level 2

1, 2, 3, [(a)] [2] B SR 3.3.7.1.1

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

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 Radiation 

Monitors

1, 2, 3, (a), 

(b)

[2] D SR 3.3.7.1.1

SR 3.3.7.1.2

SR 3.3.7.1.4

SR 3.3.7.1.5

(a) During operations with a potential for draining the reactor vessel.

(b) During movement of [recently] irradiated fuel assemblies in the [primary or secondary containment]

LOP Instrumentation (Without Setpoint Control Program)

3.3.8.1A

General Electric BWR/6 STS 3.3.8.1A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.8.1A Loss of Power (LOP) Instrumentation (Without Setpoint Control Program)

LCO 3.3.8.1A The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be 

OPERABLE.

APPLICABILITY: MODES 1, 2, and 3,

When the associated diesel generator (DG) is required to be OPERABLE 

by LCO 3.8.2, "AC Sources - Shutdown."

ACTIONS

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

Separate Condition entry is allowed for each channel.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more channels 

inoperable.

A.1 Place channel in trip. 1 hour

B. Required Action and 

associated Completion 

Time not met.

B.1 Declare associated DG 

inoperable.

Immediately
LOP Instrumentation (Without Setpoint Control Program)

3.3.8.1A

General Electric BWR/6 STS 3.3.8.1A-2 Rev. 4.0

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 hours provided the associated Function maintains DG initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.8.1.1 [ Perform CHANNEL CHECK. [ 12 hours

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 ]
LOP Instrumentation (Without Setpoint Control Program)

3.3.8.1A

General Electric BWR/6 STS 3.3.8.1A-3 Rev. 4.0

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 ]
LOP Instrumentation (Without Setpoint Control Program)

3.3.8.1A

General Electric BWR/6 STS 3.3.8.1A-4 Rev. 4.0

Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation

FUNCTION

REQUIRED

CHANNELS

PER

DIVISION

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

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]

SR 3.3.8.1.2

SR 3.3.8.1.3

SR 3.3.8.1.4

 [2621] V and  [2912] V

b. Loss of Voltage - Time Delay [4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4

 [0.4] seconds and 

 [1.0] seconds

c. Degraded Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1]

SR 3.3.8.1.2

SR 3.3.8.1.3

SR 3.3.8.1.4

 [3744] V and 

 [3837.6] V

d. Degraded Voltage - Time Delay [4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4

 [8.5] seconds and 

 [9.5] seconds

2. Division 3 - 4.16 kV Emergency Bus 

Undervoltage

a. Loss of Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1]

SR 3.3.8.1.2

SR 3.3.8.1.3

SR 3.3.8.1.4

 2984 V and  3106 V

b. Loss of Voltage - Time Delay [4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4

 [2.0] seconds and 

 [2.5] seconds

c. Degraded Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1]

SR 3.3.8.1.2

SR 3.3.8.1.3

SR 3.3.8.1.4

 3558.5 V and 

 3763.5 V

d. Degraded Voltage - Time Delay, No 

LOCA

[4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4

 [4.5] minutes and 

 [5.5] minutes

e. Degraded Voltage - Time Delay, 

LOCA

[4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4

 [3.6] seconds and 

 4.4 seconds
LOP Instrumentation (With Setpoint Control Program)

3.3.8.1B

General Electric BWR/6 STS 3.3.8.1B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.8.1B Loss of Power (LOP) Instrumentation (With Setpoint Control Program)

LCO 3.3.8.1B The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be 

OPERABLE.

APPLICABILITY: MODES 1, 2, and 3,

When the associated diesel generator (DG) is required to be OPERABLE 

by LCO 3.8.2, "AC Sources - Shutdown."

ACTIONS

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

Separate Condition entry is allowed for each channel.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more channels 

inoperable.

A.1 Place channel in trip. 1 hour

B. Required Action and 

associated Completion 

Time not met.

B.1 Declare associated DG 

inoperable.

Immediately
LOP Instrumentation (With Setpoint Control Program)

3.3.8.1B

General Electric BWR/6 STS 3.3.8.1B-2 Rev. 4.0

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 hours provided the associated Function maintains DG initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.8.1.1 [ Perform CHANNEL CHECK. [ 12 hours

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 in accordance 

with the Setpoint Control Program.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
LOP Instrumentation (With Setpoint Control Program)

3.3.8.1B

General Electric BWR/6 STS 3.3.8.1B-3 Rev. 4.0

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 ]
LOP Instrumentation (With Setpoint Control Program)

3.3.8.1B

General Electric BWR/6 STS 3.3.8.1B-4 Rev. 4.0

Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation

FUNCTION

REQUIRED CHANNELS

PER DIVISION

SURVEILLANCE

REQUIREMENTS

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]

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]

SR 3.3.8.1.3

SR 3.3.8.1.4

c. Degraded Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1]

SR 3.3.8.1.2

SR 3.3.8.1.3

SR 3.3.8.1.4

d. Degraded Voltage - Time Delay [4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

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]

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]

SR 3.3.8.1.3

SR 3.3.8.1.4

c. Degraded Voltage - 4.16 kV basis [4] [SR 3.3.8.1.1]

SR 3.3.8.1.2

SR 3.3.8.1.3

SR 3.3.8.1.4

d. Degraded Voltage - Time Delay, No LOCA [4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4

e. Degraded Voltage - Time Delay, LOCA [4] [SR 3.3.8.1.2]

SR 3.3.8.1.3

SR 3.3.8.1.4
RPS Electric Power Monitoring (Without Setpoint Control Program)

3.3.8.2A

General Electric BWR/6 STS 3.3.8.2A-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.8.2A Reactor Protection System (RPS) Electric Power Monitoring (Without Setpoint 

Control Program)

LCO 3.3.8.2A 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 

power supplies with one 

electric power 

monitoring assembly 

inoperable.

A.1 Remove associated 

inservice power supply(s) 

from service.

72 hours

B. One or both inservice 

power supplies with both 

electric power 

monitoring assemblies 

inoperable.

B.1 Remove associated 

inservice power supply(s) 

from service.

1 hour

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 1, 2, 

or 3.

C.1 --------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
RPS Electric Power Monitoring (Without Setpoint Control Program)

3.3.8.2A

General Electric BWR/6 STS 3.3.8.2A-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 4 or 5 

[with any control rod 

withdrawn from a core 

cell containing one or 

more fuel assemblies].

D.1 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

AND

D.2.1 Initiate action to restore one 

electric power monitoring 

assembly to OPERABLE 

status for inservice power 

supply(s) supplying 

required instrumentation.

 OR

D.2.2 [ Initiate action to isolate the 

Residual Heat Removal 

Shutdown Cooling System.

Immediately

Immediately

Immediately ]

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 hours.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Electric Power Monitoring (Without Setpoint Control Program)

3.3.8.2A

General Electric BWR/6 STS 3.3.8.2A-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable 

Values shall be:

a. Overvoltage

Bus A  [132.9] V

Bus B  [133.0] V

b. Undervoltage

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

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.8.2.3 Perform a system functional test. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

RPS Electric Power Monitoring (With Setpoint Control Program)

3.3.8.2B

General Electric BWR/6 STS 3.3.8.2B-1 Rev. 4.0

3.3 INSTRUMENTATION

3.3.8.2B Reactor Protection System (RPS) Electric Power Monitoring (With Setpoint Control 

Program)

LCO 3.3.8.2B 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 

power supplies with one 

electric power 

monitoring assembly 

inoperable.

A.1 Remove associated 

inservice power supply(s) 

from service.

72 hours

B. One or both inservice 

power supplies with both 

electric power 

monitoring assemblies 

inoperable.

B.1 Remove associated 

inservice power supply(s) 

from service.

1 hour

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 1, 2, 

or 3.

C.1 --------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
RPS Electric Power Monitoring (With Setpoint Control Program)

3.3.8.2B

General Electric BWR/6 STS 3.3.8.2B-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 4 or 5 

[with any control rod 

withdrawn from a core 

cell containing one or 

more fuel assemblies].

D.1 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

AND

D.2.1 Initiate action to restore one 

electric power monitoring 

assembly to OPERABLE 

status for inservice power 

supply(s) supplying 

required instrumentation.

 OR

D.2.2 [ Initiate action to isolate the 

Residual Heat Removal 

Shutdown Cooling System.

Immediately

Immediately

Immediately ]

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 hours.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RPS Electric Power Monitoring (With Setpoint Control Program)

3.3.8.2B

General Electric BWR/6 STS 3.3.8.2B-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.8.2.2 Perform CHANNEL CALIBRATION in accordance 

with the Setpoint Control Program. 

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.3.8.2.3 Perform a system functional test. [ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Recirculation Loops Operating

3.4.1

General Electric BWR/6 STS 3.4.1-1 Rev. 4.0

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

-------------------------------------------------REVIEWER’S 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 

LCO not met.

A.1 Satisfy the requirements of 

the LCO.

24 hours
Recirculation Loops Operating

3.4.1

General Electric BWR/6 STS 3.4.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

OR

No recirculation loops in 

operation.

B.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.1.1 -------------------------------NOTE------------------------------

Not required to be performed until 24 hours after 

both recirculation loops are in operation.

---------------------------------------------------------------------

Verify recirculation loop jet pump flow mismatch with 

both recirculation loops in operation is:

a.  [10]% of rated core flow when operating at 

< [70]% of rated core flow and

b.  [5]% of rated core flow when operating at 

 [70]% of rated core flow.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
FCVs

3.4.2

General Electric BWR/6 STS 3.4.2-1 Rev. 4.0

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 

FCVs inoperable.

A.1 Lock up the FCV. 4 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.2.1 Verify each FCV fails "as is" on loss of hydraulic 

pressure at the hydraulic unit.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
FCVs

3.4.2

General Electric BWR/6 STS 3.4.2-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.4.2.2 Verify average rate of each FCV movement is:

a.  [11]% of stroke per second for opening and

b.  [11]% of stroke per second for closing.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Jet Pumps

3.4.3

General Electric BWR/6 STS 3.4.3-1 Rev. 4.0

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 

inoperable.

A.1 Be in MODE 3. 12 hours
Jet Pumps

3.4.3

General Electric BWR/6 STS 3.4.3-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.3.1 ------------------------------NOTES-----------------------------

1. Not required to be performed until 4 hours after 

associated recirculation loop is in operation.

2. Not required to be performed until 24 hours 

after > 25% RTP.

---------------------------------------------------------------------

Verify at least two of the following criteria (a, b, 

and c) are satisfied for each operating recirculation 

loop:

a. Recirculation loop drive flow versus flow control 

valve position differs by 10% from established 

patterns.

b. Recirculation loop drive flow versus total core 

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.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

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

An acceptable option to these criteria for jet pump OPERABILITY can be found in the BWR/4 

STS, NUREG-1433.

-------------------------------------------------------------------------------------------------------------------------------
S/RVs

3.4.4

General Electric BWR/6 STS 3.4.4-1 Rev. 4.0

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 

inoperable.

A.1 Restore [required] S/RV to 

OPERABLE status.

14 days ]

B. [ Required Action and 

associated Completion 

Time of Condition A not 

met. ]

B.1 --------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

C. [Two] or more [required] 

S/RVs inoperable.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours
S/RVs

3.4.4

General Electric BWR/6 STS 3.4.4-2 Rev. 4.0

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 

[required] S/RVs are as follows:

Number of Setpoint

 S/RVs (psig)

[8] [1165 ± 34.9]

[6] [1180 ± 35.4]

[6] [1190 ± 35.7]

Following testing, lift settings shall be within ± 1%.

[ In accordance 

with the Inservice 

Testing Program

OR

[[18] months]

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 

on an actual or simulated automatic initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
S/RVs

3.4.4

General Electric BWR/6 STS 3.4.4-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.4.4.3 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

---------------------------------------------------------------------

Verify each [required] S/RV opens when manually 

actuated.

[ [18] months on a 

STAGGERED 

TEST BASIS for 

each valve 

solenoid

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

RCS Operational LEAKAGE

3.4.5

General Electric BWR/6 STS 3.4.5-1 Rev. 4.0

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 hour 

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. Unidentified LEAKAGE 

not within limit.

OR

Total LEAKAGE not 

within limit.

A.1 Reduce LEAKAGE to within 

limits.

4 hours

B. Unidentified LEAKAGE 

increase not within limit.

B.1 Reduced LEAKAGE to 

within limit.

OR

B.2 Verify source of unidentified 

LEAKAGE increase is not 

service sensitive type 304 

or type 316 austenitic 

stainless steel.

4 hours

4 hours
RCS Operational LEAKAGE

3.4.5

General Electric BWR/6 STS 3.4.5-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

OR

Pressure boundary 

LEAKAGE exists.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.5.1 Verify RCS unidentified and total LEAKAGE and 

unidentified LEAKAGE increase are within limits.

[ 8 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCS PIV Leakage

3.4.6

General Electric BWR/6 STS 3.4.6-1 Rev. 4.0

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 

with leakage from one or 

more RCS PIVs not 

within limit.

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

Each valve used to satisfy Required 

Action A.1 and Required Action A.2 

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 

portion of the affected 

system from the low 

pressure portion by use of 

one closed manual, 

deactivated automatic, or 

check valve.

AND

4 hours
RCS PIV Leakage

3.4.6

General Electric BWR/6 STS 3.4.6-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2 Isolate the high pressure 

portion of the affected 

system from the low 

pressure portion by use of a 

second closed manual, 

deactivated automatic, or 

check valve.

72 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

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 

 0.5 gpm per nominal inch of valve size up to a 

maximum of 5 gpm, at an RCS pressure 

 [1040] psig and  [1060] psig.

[ In accordance 

with Inservice 

Testing Program

OR

[[18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCS Leakage Detection Instrumentation

3.4.7

General Electric BWR/6 STS 3.4.7-1 Rev. 4.0

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 

monitoring system 

inoperable.

A.1 Restore drywell floor drain 

sump monitoring system to 

OPERABLE status.

30 days

B. Required drywell 

atmospheric monitoring 

system inoperable.

B.1 Analyze grab samples of 

drywell atmosphere.

AND

B.2 [ Restore required drywell 

atmospheric monitoring 

system to OPERABLE 

status.

Once per 12 hours

30 days ]
RCS Leakage Detection Instrumentation

3.4.7

General Electric BWR/6 STS 3.4.7-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. [ Drywell air cooler 

condensate flow rate 

monitoring system 

inoperable.

C.1 --------------NOTE--------------

Not applicable when the 

required drywell 

atmospheric monitoring 

system is inoperable.

-------------------------------------

Perform SR 3.4.7.1. Once per 8 hours ]

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

Only applicable when the 

drywell atmospheric 

gaseous monitoring system

is the only OPERABLE 

monitor.

-------------------------------------

D. Drywell floor drain sump 

monitoring system 

inoperable.

AND

[ Drywell air cooler 

condensate flow rate 

monitoring system

inoperable. ]

D.1 Analyze grab samples of 

the drywell atmosphere.

AND

D.2 Monitor RCS LEAKAGE by 

administrative means.

AND

D.3.1 Restore drywell floor drain 

sump monitoring system to 

OPERABLE status.

 OR

[ D.3.2 Restore drywell air cooler 

condensate flow rate 

monitoring system to 

OPERABLE status.

Once per 12 hours

Once per 12 hours

7 days

7 days ]

E. [ Required drywell 

atmospheric monitoring 

system inoperable.

AND

Drywell air cooler

condensate flow rate 

monitoring system 

inoperable.

E.1 Restore required drywell 

atmospheric monitoring 

system to OPERABLE 

status.

OR

E.2 Restore drywell air cooler 

condensate flow rate 

monitoring system to 

OPERABLE status.

30 days

30 days ]
RCS Leakage Detection Instrumentation

3.4.7

General Electric BWR/6 STS 3.4.7-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F. Required Action and 

associated Completion 

Time of Condition A, B, 

[C, D, or E] not met.

F.1 Be in MODE 3.

AND

F.2 Be in MODE 4.

12 hours

36 hours

G. All required leakage 

detection systems 

inoperable.

G.1 Enter LCO 3.0.3. Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.7.1 Perform CHANNEL CHECK of required drywell 

atmospheric monitoring system.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCS Leakage Detection Instrumentation

3.4.7

General Electric BWR/6 STS 3.4.7-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of required 

leakage detection instrumentation.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.4.7.3 Perform CHANNEL CALIBRATION of required 

leakage detection instrumentation.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCS Specific Activity

3.4.8

General Electric BWR/6 STS 3.4.8-1 Rev. 4.0

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 

activity > [0.2] Ci/gm 

and  4.0 Ci/gm DOSE 

EQUIVALENT I-131.

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

LCO 3.0.4.c is applicable.

------------------------------------------------

A.1 Determine DOSE 

EQUIVALENT I-131.

AND

A.2 Restore DOSE 

EQUIVALENT I-131 to 

within limits.

Once per 4 hours

48 hours

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

OR

Reactor coolant 

specific activity 

> [4.0] Ci/gm DOSE 

EQUIVALENT I-131.

B.1 Determine DOSE 

EQUIVALENT I-131.

AND

B.2.1 Isolate all main steam lines.

OR

B.2.2.1 Be in MODE 3.

AND

Once per 4 hours

12 hours

12 hours
RCS Specific Activity

3.4.8

General Electric BWR/6 STS 3.4.8-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2.2.2 Be in MODE 4. 36 hours

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 

specific activity is  [0.2] Ci/gm.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RHR Shutdown Cooling System - Hot Shutdown

3.4.9

General Electric BWR/6 STS 3.4.9-1 Rev. 4.0

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 hours per 8 hour period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 

2 hours 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 or two RHR 

shutdown cooling 

subsystems inoperable.

A.1 Initiate action to restore 

RHR shutdown cooling 

subsystem to OPERABLE 

status.

AND

Immediately
RHR Shutdown Cooling System - Hot Shutdown

3.4.9

General Electric BWR/6 STS 3.4.9-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2 Verify an alternate method 

of decay heat removal is 

available for each 

inoperable RHR shutdown 

cooling subsystem.

AND

A.3 Be in MODE 4.

1 hour

24 hours

B. No RHR shutdown 

cooling subsystem in 

operation.

AND

No recirculation pump in 

operation.

B.1 Initiate action to restore one 

RHR shutdown cooling 

subsystem or one 

recirculation pump to 

operation.

AND

B.2 Verify reactor coolant 

circulation by an alternate 

method.

AND

B.3 Monitor reactor coolant 

temperature and pressure.

Immediately

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per 12 hours 

thereafter

Once per hour
RHR Shutdown Cooling System - Hot Shutdown

3.4.9

General Electric BWR/6 STS 3.4.9-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.9.1 -------------------------------NOTE------------------------------

Not required to be met until 2 hours after reactor 

steam dome pressure is < [the RHR cut in 

permissive pressure].

---------------------------------------------------------------------

Verify one RHR shutdown cooling subsystem or 

recirculation pump is operating.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

RHR Shutdown Cooling System - Cold Shutdown

3.4.10

General Electric BWR/6 STS 3.4.10-1 Rev. 4.0

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 hours per 8 hour period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 

2 hours 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 

shutdown cooling 

subsystems inoperable.

A.1 Verify an alternate method 

of decay heat removal is 

available for each 

inoperable RHR shutdown 

cooling subsystem.

1 hour

AND

Once per 24 hours 

thereafter
RHR Shutdown Cooling System - Cold Shutdown

3.4.10

General Electric BWR/6 STS 3.4.10-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. No RHR shutdown 

cooling subsystem in 

operation.

AND

No recirculation pump in 

operation.

B.1 Verify reactor coolant 

circulating by an alternate 

method.

AND

B.2 Monitor reactor coolant 

temperature and pressure.

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per 12 hours 

thereafter

Once per hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or 

recirculation pump is operating.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCS P/T Limits

3.4.11

General Electric BWR/6 STS 3.4.11-1 Rev. 4.0

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------------

Required Action A.2 

shall be completed if this 

Condition is entered.

---------------------------------

Requirements of the 

LCO not met in 

MODES 1, 2, and 3.

A.1 Restore parameter(s) to 

within limits.

AND

A.2 Determine RCS is 

acceptable for continued 

operation.

30 minutes

72 hours

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

C. ------------NOTE------------

Required Action C.2 

shall be completed if this 

Condition is entered.

---------------------------------

Requirements of the 

LCO not met in other 

than MODES 1, 2, 

and 3.

C.1 Initiate action to restore 

parameter(s) to within 

limits.

AND

C.2 Determine RCS is 

acceptable for operation.

Immediately

Prior to entering 

MODE 2 or 3
RCS P/T Limits

3.4.11

General Electric BWR/6 STS 3.4.11-2 Rev. 4.0

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 

heatup and cooldown rates are within the limits 

specified in the PTLR.

[ 30 minutes

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.4.11.2 Verify RCS pressure and RCS temperature are 

within the criticality limits specified in the PTLR.

Once within 

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 

coolant temperature and the reactor pressure vessel 

(RPV) coolant temperature is within the limits 

specified in the PTLR.

Once within 

15 minutes prior

to each startup of 

a recirculation 

pump
RCS P/T Limits

3.4.11

General Electric BWR/6 STS 3.4.11-3 Rev. 4.0

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 

temperature in the recirculation loop to be started 

and the RPV coolant temperature is within the limits 

specified in the PTLR.

Once within 

15 minutes prior 

to each startup of 

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 

coolant temperature and the RPV coolant 

temperature is [ 145F].

Once within 

15 minutes prior 

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 

temperature in the idle recirculation loop and the 

RPV coolant temperature is [ 50F].

Once within 

15 minutes prior 

to a THERMAL 

POWER increase 

or recirculation 

flow increase ]
RCS P/T Limits

3.4.11

General Electric BWR/6 STS 3.4.11-4 Rev. 4.0

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 

temperatures are within the limits specified in the 

PTLR.

[ 30 minutes

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  80F in MODE 4.

---------------------------------------------------------------------

Verify reactor vessel flange and head flange 

temperatures are within the limits specified in the 

PTLR.

[ 30 minutes

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCS P/T Limits

3.4.11

General Electric BWR/6 STS 3.4.11-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.4.11.9 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

RCS temperature  100F in MODE 4.

---------------------------------------------------------------------

Verify reactor vessel flange and head flange 

temperatures are within the limits specified in the 

PTLR.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Reactor Steam Dome Pressure

3.4.12

General Electric BWR/6 STS 3.4.12-1 Rev. 4.0

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 

pressure not within limit.

A.1 Restore reactor steam 

dome pressure to within 

limit.

15 minutes

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.12.1 Verify reactor steam dome pressure is  [1045] psig. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

ECCS - Operating

3.5.1

General Electric BWR/6 STS 3.5.1-1 Rev. 4.0

3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION 

COOLING SYSTEM (RCIC)

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 HPCS.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One low pressure ECCS 

injection/spray 

subsystem inoperable.

A.1 Restore low pressure 

ECCS injection/spray 

subsystem to OPERABLE 

status.

7 days

B. High Pressure Core 

Spray (HPCS) System 

inoperable.

B.1 Verify by administrative 

means RCIC System is 

OPERABLE when RCIC is 

required to be OPERABLE.

AND

B.2 Restore HPCS System to 

OPERABLE status.

Immediately

14 days
ECCS - Operating

3.5.1

General Electric BWR/6 STS 3.5.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Two ECCS injection 

subsystems inoperable.

OR

One ECCS injection and 

one ECCS spray 

subsystem inoperable.

C.1 Restore one ECCS 

injection/spray subsystem 

to OPERABLE status.

72 hours

D. Required Action and 

associated Completion 

Time of Condition A, B, 

or C not met.

D.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

E. One ADS valve 

inoperable.

E.1 Restore ADS valve to 

OPERABLE status.

14 days

F. One ADS valve 

inoperable.

AND

One low pressure ECCS 

injection/spray 

subsystem inoperable.

F.1 Restore ADS valve to 

OPERABLE status.

OR

F.2 Restore low pressure 

ECCS injection/spray 

subsystem to OPERABLE 

status.

72 hours

72 hours

G. Two or more ADS valves 

inoperable.

OR

Required Action and 

associated Completion 

Time of Condition E or F 

not met.

G.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
ECCS - Operating

3.5.1

General Electric BWR/6 STS 3.5.1-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

H. HPCS and low pressure 

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.

H.1 Enter LCO 3.0.3. Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, 

the piping is filled with water from the pump 

discharge valve to the injection valve.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ECCS - Operating

3.5.1

General Electric BWR/6 STS 3.5.1-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.1.2 Verify each ECCS injection/spray subsystem 

manual, power operated, and automatic valve in the 

flow path, that is not locked, sealed, or otherwise 

secured in position, is in the correct position.

[ 31 days

OR

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 

rate [against a system head corresponding to the 

specified reactor pressure].

[System Head

Corresponding to a

Reactor

System Flow Rate Pressure of]

LPCS  [7115] gpm  [290] psig

LPCI  [7450] gpm  [125] psig

HPCS  [7115] gpm  [445] psig

[ In accordance 

with the Inservice 

Testing Program

OR

[92 days]

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ECCS - Operating

3.5.1

General Electric BWR/6 STS 3.5.1-5 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.1.5 -------------------------------NOTE------------------------------

Vessel injection/spray may be excluded.

---------------------------------------------------------------------

Verify each ECCS injection/spray subsystem 

actuates on an actual or simulated automatic 

initiation signal.

[ [18] months

OR

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 

automatic initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ECCS - Operating

3.5.1

General Electric BWR/6 STS 3.5.1-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.1.7 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

---------------------------------------------------------------------

Verify each ADS valve opens when manually 

actuated.

[ [18] months on a 

STAGGERED 

TEST BASIS for 

each valve 

solenoid

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ECCS - Shutdown

3.5.2

General Electric BWR/6 STS 3.5.2-1 Rev. 4.0

3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION 

COOLING SYSTEM (RCIC)

3.5.2 ECCS - Shutdown

LCO 3.5.2 Two ECCS injection/spray subsystems shall be OPERABLE.

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

One low pressure coolant injection (LPCI) subsystem may be considered 

OPERABLE during alignment and operation for decay heat removal, if 

capable of being manually realigned and not otherwise inoperable.

--------------------------------------------------------------------------------------------------

APPLICABILITY: MODE 4,

MODE 5 except with the upper containment [cavity to dryer] pool [gate] 

removed and water level  [22 ft 8 inches] over the top of the reactor 

pressure vessel flange.

ACTIONS

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

LCO 3.0.4.b is not applicable to RCIC.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One required ECCS 

injection/spray 

subsystem inoperable.

A.1 Restore required ECCS 

injection/spray subsystem 

to OPERABLE status.

4 hours

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel (OPDRVs).

Immediately

C. Two required ECCS 

injection/spray 

subsystems inoperable.

C.1 Initiate action to suspend 

OPDRVs.

AND

C.2 Restore one ECCS 

injection/spray subsystem 

to OPERABLE status.

Immediately

4 hours
ECCS - Shutdown

3.5.2

General Electric BWR/6 STS 3.5.2-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action C.2 and 

associated Completion 

Time not met.

D.1 Initiate action to restore 

[secondary containment] to 

OPERABLE status.

AND

D.2 [ Initiate action to restore 

one standby gas treatment 

subsystem to OPERABLE 

status.

AND

D.3 Initiate action to restore 

isolation capability in each 

required [secondary 

containment] penetration 

flow path not isolated.

Immediately

Immediately ]

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.5.2.1 Verify, for each required low pressure ECCS 

injection/spray subsystem, the suppression pool 

water level is  [12.67 ft].

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ECCS - Shutdown

3.5.2

General Electric BWR/6 STS 3.5.2-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.2.2 Verify, for the required High Pressure Core Spray 

(HPCS) System, the:

a. Suppression pool water level is  [12.67 ft] or

b. Condensate storage tank water level is  [18 ft].

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.5.2.3 Verify, for each required ECCS injection/spray 

subsystem, the piping is filled with water from the 

pump discharge valve to the injection valve.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.5.2.4 Verify each required ECCS injection/spray 

subsystem manual, power operated, and automatic 

valve in the flow path, that is not locked, sealed, or 

otherwise secured in position, is in the correct 

position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
ECCS - Shutdown

3.5.2

General Electric BWR/6 STS 3.5.2-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.2.5 Verify each required ECCS pump develops the 

specified flow rate [against a system head 

corresponding to the specified reactor pressure].

[System Head

Corresponding to

a Reactor

System Flow Rate Pressure of]

LPCS  [7115] gpm  [290] psig

LPCI  [7450] gpm  [125] psig

HPCS  [7115] gpm  [445] psig

[ In accordance 

with the Inservice 

Testing Program 

OR

[92 days]

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.5.2.6 -------------------------------NOTE------------------------------

Vessel injection/spray may be excluded.

---------------------------------------------------------------------

Verify each required ECCS injection/spray 

subsystem actuates on an actual or simulated 

automatic initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCIC System

3.5.3

General Electric BWR/6 STS 3.5.3-1 Rev. 4.0

3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION 

COOLING SYSTEM (RCIC)

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 

inoperable.

A.1 Verify by administrative 

means High Pressure Core 

Spray System is 

OPERABLE.

AND

A.2 Restore RCIC System to 

OPERABLE status.

Immediately

14 days

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Reduce reactor steam 

dome pressure to 

 [150] psig.

12 hours

36 hours
RCIC System

3.5.3

General Electric BWR/6 STS 3.5.3-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.5.3.1 Verify the RCIC System piping is filled with water 

from the pump discharge valve to the injection 

valve.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.5.3.2 Verify each RCIC System manual, power operated, 

and automatic valve in the flow path, that is not 

locked, sealed, or otherwise secured in position, is 

in the correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.5.3.3 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

---------------------------------------------------------------------

Verify, with [RCIC steam supply pressure] 

 [1045] psig and  [945] psig, the RCIC pump can 

develop a flow rate  [800] gpm [against a system 

head corresponding to reactor pressure].

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RCIC System

3.5.3

General Electric BWR/6 STS 3.5.3-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.3.4 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

---------------------------------------------------------------------

Verify, with [RCIC steam supply pressure] 

 [165] psig, the RCIC pump can develop a flow rate 

 [800] gpm [against a system head corresponding 

to reactor pressure].

[ [18] months

OR

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 

simulated automatic initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Primary Containment

3.6.1.1

General Electric BWR/6 STS 3.6.1.1-1 Rev. 4.0

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 

inoperable.

A.1 Restore primary 

containment to OPERABLE 

status.

1 hour

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.1.1 Perform required visual examinations and leakage 

rate testing except for primary containment air lock 

testing, in accordance with the Primary Containment 

Leakage Rate Testing Program.

In accordance 

with the Primary 

Containment 

Leakage Rate 

Testing Program

SR 3.6.1.1.2 [ Verify primary containment structural integrity in 

accordance with the Primary Containment Tendon 

Surveillance Program.

In accordance 

with the Primary 

Containment

Tendon 

Surveillance 

Program ]

Primary Containment Air Locks

3.6.1.2

General Electric BWR/6 STS 3.6.1.2-1 Rev. 4.0

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 

containment air locks 

with one primary 

containment air lock 

door inoperable.

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

1. Required Actions A.1, A.2, 

and A.3 are not applicable if both 

doors in the same air lock are 

inoperable and Condition C is 

entered.

2. Entry and exit is permissible for 

7 days under administrative 

controls [if both air locks are 

inoperable].

------------------------------------------------
Primary Containment Air Locks

3.6.1.2

General Electric BWR/6 STS 3.6.1.2-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.1 Verify the OPERABLE door 

is closed in the affected air 

lock.

AND

A.2 Lock the OPERABLE door 

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 

is locked closed in the 

affected air lock.

1 hour

24 hours

Once per 31 days
Primary Containment Air Locks

3.6.1.2

General Electric BWR/6 STS 3.6.1.2-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. One or more primary 

containment air locks 

with primary 

containment air lock 

interlock mechanism 

inoperable.

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

1. Required Actions B.1, B.2, 

and B.3 are not applicable if both 

doors in the same air lock are 

inoperable and Condition C is 

entered.

2. Entry into and exit from 

containment is permissible under 

the control of a dedicated 

individual.

------------------------------------------------

B.1 Verify an OPERABLE door 

is closed in the affected air 

lock.

AND

B.2 Lock an OPERABLE door 

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 

is locked closed in the 

affected air lock.

1 hour

24 hours

Once per 31 days
Primary Containment Air Locks

3.6.1.2

General Electric BWR/6 STS 3.6.1.2-4 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. One or more primary 

containment air locks 

inoperable for reasons 

other than Condition A 

or B.

C.1 Initiate action to evaluate 

primary containment overall 

leakage rate per 

LCO 3.6.1.1, using current 

air lock test results.

AND

C.2 Verify a door is closed in 

the affected air lock.

AND

C.3 Restore air lock to 

OPERABLE status.

Immediately

1 hour

24 hours

D. Required Action and 

associated Completion 

Time not met.

D.1 Be in MODE 3.

AND

D.2 Be in MODE 4.

12 hours

36 hours
Primary Containment Air Locks

3.6.1.2

General Electric BWR/6 STS 3.6.1.2-5 Rev. 4.0

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 

leakage rate testing in accordance with the Primary 

Containment Leakage Rate Testing Program.

In accordance 

with the Primary 

Containment 

Leakage Rate 

Testing Program

SR 3.6.1.2.2 [ Verify primary containment air lock seal air flask 

pressure is  [90] psig.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.6.1.2.3 Verify only one door in the primary containment air 

lock can be opened at a time.

[ 24 months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Primary Containment Air Locks

3.6.1.2

General Electric BWR/6 STS 3.6.1.2-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.2.4 [ Verify, from an initial pressure of [90] psig, the 

primary containment air lock seal pneumatic system 

pressure does not decay at a rate equivalent to 

> [2] psig for a period of [48] hours.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-1 Rev. 4.0

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.

-------------------------------------------------------------------------------------------------------------------------------
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A. ------------NOTE------------

Only applicable to 

penetration flow paths 

with two [or more] 

PCIVs.

---------------------------------

One or more penetration 

flow paths with one 

PCIV inoperable [for 

reasons other than 

Condition[s] D [and E]].

A.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

blind flange, or check valve 

with flow through the valve 

secured.

AND

4 hours [for feedwater 

isolation valves 

(FWIVs), residual 

heat removal (RHR) 

shutdown cooling 

suction lines PCIVs, 

and Low Pressure 

Core Spray (LPCS) 

System PCIVs]

AND

8 hours for main 

steam isolation valves 

(MSIVs)

[ AND

7 days except for 

FWIVs, RHR 

shutdown cooling 

suction line PCIVs, 

LPCS System PCIVs, 

and MSIVs ]
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-3 Rev. 4.0

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 

penetration flow path is 

isolated.

Once per 31 days 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
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-4 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. ------------NOTE------------

Only applicable to 

penetration flow paths 

with two [or more] 

PCIVs.

---------------------------------

One or more penetration 

flow paths with two [or 

more] PCIVs inoperable 

[for reasons other than 

Condition[s] D [and E]].

B.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange.

1 hour

C. ------------NOTE------------

Only applicable to 

penetration flow paths 

with only one PCIV.

---------------------------------

One or more penetration 

flow paths with one 

PCIV inoperable [for 

reasons other than 

Condition[s] D [and E]].

C.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange.

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 

penetration flow path is 

isolated.

[4] hours except for 

penetrations with a 

closed system

AND

[7 days] for 

penetrations with a 

closed system

Once per 31 days
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-5 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. [ One or more 

[secondary containment 

bypass leakage rate,] 

[MSIV leakage rate,] 

[purge valve leakage 

rate,] [or] [hydrostatically 

tested line leakage rate] 

not within limit.

D.1 Restore leakage rate to 

within limit.

[4 hours for 

hydrostatically tested 

line leakage [not on a 

closed system]

AND

[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 

penetration flow paths 

with one or more 

containment purge 

valves not within purge 

valve leakage limits.

E.1 Isolate the affected 

penetration flow path by 

use of at least one [closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange].

AND

24 hours
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-6 Rev. 4.0

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 

penetration flow path is 

isolated.

AND

E.3 Perform SR 3.6.1.3.6 for 

the resilient seal purge 

valves closed to comply 

with Required Action E.1.

Once per 31 days 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

Once per [92] days ]

F. Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, or E not met in 

MODE 1, 2, or 3.

F.1 Be in MODE 3.

AND

F.2 Be in MODE 4.

12 hours

36 hours
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-7 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

G. [ Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, or E not met for 

PCIV(s) required to be 

OPERABLE during 

movement of [recently] 

irradiated fuel 

assemblies in the 

[primary or secondary 

containment].

G.1 ---------------NOTE--------------

LCO 3.0.3 is not applicable.

-------------------------------------

Suspend movement of 

[recently] irradiated fuel 

assemblies in [primary and 

secondary containment].

Immediately ]

H. [ Required Action and 

Associated Completion 

Time of Condition A, B, 

C, D, or E not met for 

PCIV(s) required to be 

OPERABLE during 

MODE 4 or 5 or during 

operations with a 

potential for draining the 

reactor vessel 

(OPDRVs).

H.1 Initiate action to suspend 

OPDRVs.

OR

H.2 Initiate action to restore 

valve(s) to OPERABLE 

status.

Immediately

Immediately ]
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-8 Rev. 4.0

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 

valve is sealed closed except for one purge valve in 

a penetration flow path while in Condition E of this 

LCO.

[ 31 days

OR

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 

valve is closed.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-9 Rev. 4.0

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 

valve and blind flange that is located outside primary 

containment, drywell, and steam tunnel and not 

locked, sealed, or otherwise secured and is required 

to be closed during accident conditions is closed.

[ 31 days

OR

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 

valve and blind flange that is located inside primary 

containment, drywell, or steam tunnel and not 

locked, sealed, or otherwise secured and is required 

to be closed during accident conditions is closed.

Prior to entering 

MODE 2 or 3 from 

MODE 4, if not 

performed within 

the previous 

92 days
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-10 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.3.5 Verify the isolation time of each power operated, 

automatic PCIV[, except MSIVs,] is within limits.

[ In accordance 

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 

containment purge valve with resilient seals.

[ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

AND

Once within 

92 days after 

opening the 

valve ]
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-11 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.3.7 Verify the isolation time of each MSIV is 

 [3] seconds and  [5] seconds.

[ In accordance 

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 

position on an actual or simulated isolation signal.

[ [18] months

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 

containment bypass leakage paths is  [ ] La when 

pressurized to  [ ] psig.

In accordance 

with the Primary 

Containment 

Leakage Rate 

Testing Program ]

SR 3.6.1.3.10 -------------------------------NOTE------------------------------

[Only required to be met in MODES 1, 2, and 3.]

---------------------------------------------------------------------

Verify leakage rate through all four main steam lines 

is  [100] scfh when tested at  [11.5] psig.

[In accordance 

with the Primary 

Containment 

Leakage Rate 

Testing Program]
PCIVs

3.6.1.3

General Electric BWR/6 STS 3.6.1.3-12 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.3.11 -------------------------------NOTE------------------------------

[Only required to be met in MODES 1, 2, and 3.]

---------------------------------------------------------------------

Verify combined leakage rate through hydrostatically 

tested lines that penetrate the primary containment 

is within limits.

In accordance 

with the Primary 

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 

valve is blocked to restrict the valve from opening 

> [50]%.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
Primary Containment Pressure

3.6.1.4

General Electric BWR/6 STS 3.6.1.4-1 Rev. 4.0

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 

secondary containment 

differential] pressure not 

within limits.

A.1 Restore primary 

containment [to secondary 

containment differential] 

pressure to within limits.

1 hour

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.4.1 Verify primary containment [to secondary 

containment differential] pressure is within limits.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Primary Containment Air Temperature

3.6.1.5

General Electric BWR/6 STS 3.6.1.5-1 Rev. 4.0

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 

average air temperature 

not within limit.

A.1 Restore primary 

containment average air 

temperature to within limit.

8 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.5.1 Verify primary containment average air temperature 

is within limit.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

LLS Valves

3.6.1.6

General Electric BWR/6 STS 3.6.1.6-1 Rev. 4.0

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 

inoperable.

A.1 Restore LLS valve to 

OPERABLE status.

14 days

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

C. Two or more LLS valves 

inoperable.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours
LLS Valves

3.6.1.6

General Electric BWR/6 STS 3.6.1.6-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.6.1 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

---------------------------------------------------------------------

Verify each LLS valve opens when manually 

actuated.

[ [18] months [on 

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 

simulated automatic initiation signal.

[ 18 months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RHR Containment Spray System

3.6.1.7

General Electric BWR/6 STS 3.6.1.7-1 Rev. 4.0

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 

spray subsystem 

inoperable.

A.1 Restore RHR containment 

spray subsystem to 

OPERABLE status.

7 days

B. Two RHR containment 

spray subsystems 

inoperable.

B.1 Restore one RHR 

containment spray 

subsystem to OPERABLE 

status.

8 hours

C. Required Action and 

associated Completion 

Time not met.

C.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
RHR Containment Spray System

3.6.1.7

General Electric BWR/6 STS 3.6.1.7-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.7.1 -------------------------------NOTE------------------------------

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.

---------------------------------------------------------------------

Verify each RHR containment spray subsystem 

manual, power operated, and automatic valve in the 

flow path that is not locked, sealed, or otherwise 

secured in position is in the correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.1.7.2 Verify each RHR pump develops a flow rate of 

 [5650] gpm on recirculation flow through the 

associated heat exchanger to the suppression pool.

[ In accordance 

with the Inservice 

Testing Program

OR

[92 days]

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
RHR Containment Spray System

3.6.1.7

General Electric BWR/6 STS 3.6.1.7-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.7.3 Verify each RHR containment spray subsystem 

automatic valve in the flow path actuates to its 

correct position on an actual or simulated automatic 

initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.1.7.4 Verify each spray nozzle is unobstructed. [At first refueling]

AND

[ 10 years

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

PVLCS

3.6.1.8

General Electric BWR/6 STS 3.6.1.8-1 Rev. 4.0

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 

inoperable.

A.1 Restore PVLCS 

subsystems to OPERABLE 

status.

30 days

B. [Two] PVLCS 

subsystems inoperable.

B.1 Restore one PVLCS 

subsystem to OPERABLE 

status.

7 days

C. Required Action and 

associated Completion 

Time not met.

C.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
PVLCS

3.6.1.8

General Electric BWR/6 STS 3.6.1.8-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.8.1 Verify air pressure in each subsystem is 

 [101] psig.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.1.8.2 Perform a system functional test of each PVLCS 

subsystem.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
MSIV LCS

3.6.1.9

General Electric BWR/6 STS 3.6.1.9-1 Rev. 4.0

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 

subsystem inoperable.

A.1 Restore MSIV LCS 

subsystem to OPERABLE 

status.

30 days

B. Two MSIV LCS 

subsystems inoperable.

B.1 Restore one MSIV LCS 

subsystem to OPERABLE 

status.

7 days

C. Required Action and 

associated Completion 

Time not met.

C.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
MSIV LCS

3.6.1.9

General Electric BWR/6 STS 3.6.1.9-2 Rev. 4.0

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 

LCS subsystem heater element circuitry.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.1.9.3 Perform a system functional test of each MSIV LCS 

subsystem.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Suppression Pool Average Temperature

3.6.2.1

General Electric BWR/6 STS 3.6.2.1-1 Rev. 4.0

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 

average temperature 

> [95]F but  [110]F.

AND

[Any OPERABLE IRM 

channel > [25/40] 

divisions of full scale on 

Range 7] [THERMAL 

POWER > 1% RTP].

AND

Not performing testing 

that adds heat to the 

suppression pool.

A.1 Verify suppression pool

average temperature is 

 [110]F.

AND

A.2 Restore suppression pool 

average temperature to 

 [95]F.

Once per hour

24 hours
Suppression Pool Average Temperature

3.6.2.1

General Electric BWR/6 STS 3.6.2.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Reduce THERMAL 

POWER [until all 

OPERABLE IRM channels 

are  [25/40] divisions of full 

scale on Range 7] [to 

 1% RTP].

12 hours

C. Suppression pool 

average temperature 

> [105]F.

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.

C.1 Suspend all testing that 

adds heat to the 

suppression pool.

Immediately

D. Suppression pool 

average temperature 

> [110]F but  [120]F.

D.1 Place the reactor mode 

switch in the shutdown 

position.

AND

D.2 Verify suppression pool 

average temperature is 

 [120]F.

AND

D.3 Be in MODE 4.

Immediately

Once per 30 minutes

36 hours
Suppression Pool Average Temperature

3.6.2.1

General Electric BWR/6 STS 3.6.2.1-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. Suppression pool 

average temperature 

> [120]F.

E.1 Depressurize the reactor 

vessel to < [200] psig.

AND

E.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.2.1.1 Verify suppression pool average temperature is 

within the applicable limits.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

AND

5 minutes when 

performing testing 

that adds heat to 

the suppression 

pool

Suppression Pool Water Level

3.6.2.2

General Electric BWR/6 STS 3.6.2.2-1 Rev. 4.0

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 

level not within limits.

A.1 Restore suppression pool 

water level to within limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.2.2.1 Verify suppression pool water level is within limits. [ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

RHR Suppression Pool Cooling

3.6.2.3

General Electric BWR/6 STS 3.6.2.3-1 Rev. 4.0

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 

pool cooling subsystem 

inoperable.

A.1 Restore RHR suppression 

pool cooling subsystem to 

OPERABLE status.

7 days

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be MODE 3. 12 hours

C. Two RHR suppression

pool cooling subsystems 

inoperable.

C.1 Restore one RHR 

suppression pool cooling 

subsystem to OPERABLE 

status.

8 hours

D. Required Action and 

associated Completion 

Time of Condition C not 

met.

D.1 Be in MODE 3.

AND

D.2 Be in MODE 4.

12 hours

36 hours
RHR Suppression Pool Cooling

3.6.2.3

General Electric BWR/6 STS 3.6.2.3-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.2.3.1 Verify each RHR suppression pool cooling 

subsystem manual, power operated, and automatic 

valve in the flow path that is not locked, sealed, or 

otherwise secured in position is in the correct 

position or can be aligned to the correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate 

 [7450] gpm through the associated heat 

exchanger while operating in the suppression pool 

cooling mode.

[ In accordance 

with the Inservice 

Testing Program

OR

[92 days]

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SPMU System

3.6.2.4

General Electric BWR/6 STS 3.6.2.4-1 Rev. 4.0

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 

water level not within 

limit.

A.1 Restore upper containment 

pool water level to within 

limit.

4 hours

B. Upper containment pool 

water temperature not 

within limit.

B.1 Restore upper containment 

pool water temperature to 

within limit.

24 hours

C. One SPMU subsystem 

inoperable for reasons 

other than Condition A 

or B.

C.1 Restore SPMU subsystem 

to OPERABLE status.

7 days

D. Required Action and 

associated Completion 

Time not met.

D.1 Be in MODE 3.

AND

D.2 Be in MODE 4.

12 hours

36 hours
SPMU System

3.6.2.4

General Electric BWR/6 STS 3.6.2.4-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.2.4.1 Verify upper containment pool water level is  [23 ft 

3 inches] above the pool bottom.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.2.4.2 Verify upper containment pool water temperature is 

 [125]F.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.2.4.3 Verify each SPMU subsystem manual, power 

operated, and automatic valve that is not locked, 

sealed, or otherwise secured in position is in the 

correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.2.4.4 [ Verify all upper containment pool gates are in the 

stored position or are otherwise removed from the 

upper containment pool.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
SPMU System

3.6.2.4

General Electric BWR/6 STS 3.6.2.4-3 Rev. 4.0

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 

actuates to the correct position on an actual or 

simulated automatic initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Primary Containment and Drywell Hydrogen Ignitors

3.6.3.1

General Electric BWR/6 STS 3.6.3.1-1 Rev. 4.0

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 

containment and drywell 

hydrogen ignitor division 

inoperable.

A.1 Restore primary 

containment and drywell 

hydrogen ignitor division to 

OPERABLE status.

30 days

B. Two primary 

containment and drywell 

hydrogen ignitor 

divisions inoperable.

B.1 Verify by administrative 

means that the hydrogen 

control function is 

maintained.

AND

B.2 Restore one primary 

containment and drywell 

hydrogen ignitor division to 

OPERABLE status.

1 hour

AND

Once per 12 hours 

thereafter

7 days

C. Required Action and 

associated Completion 

Time not met.

C.1 Be in MODE 3. 12 hours
Primary Containment and Drywell Hydrogen Ignitors

3.6.3.1

General Electric BWR/6 STS 3.6.3.1-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.3.1.1 Energize each primary containment and drywell 

hydrogen ignitor division and perform current versus 

voltage measurements to verify required ignitors in 

service.

[ 184 days

OR

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 

hydrogen ignitor division and perform current versus 

voltage measurements to verify required ignitors in 

service.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.3.1.3 Verify each required ignitor in inaccessible areas 

develops sufficient current draw for a  [1700]F 

surface temperature.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Primary Containment and Drywell Hydrogen Ignitors

3.6.3.1

General Electric BWR/6 STS 3.6.3.1-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.3.1.4 Verify each required ignitor in accessible areas 

develops a surface temperature of  [1700]F.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

[Drywell Purge System]

3.6.3.2

General Electric BWR/6 STS 3.6.3.2-1 Rev. 4.0

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] 

subsystem inoperable.

A.1 Restore [drywell purge] 

subsystem to OPERABLE 

status.

30 days

B. Two [drywell purge] 

subsystems inoperable.

B.1 Verify by administrative 

means that the hydrogen 

control function is 

maintained.

AND

B.2 Restore one [drywell purge] 

subsystem to OPERABLE 

status.

1 hour

AND

Once per 12 hours 

thereafter

7 days

C. Required Action and 

associated Completion 

Time not met.

C.1 Be in MODE 3. 12 hours
[Drywell Purge System]

3.6.3.2

General Electric BWR/6 STS 3.6.3.2-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.3.2.1 Operate each [drywell purge] subsystem for 

 [15] minutes.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.3.2.2 [ Verify each [drywell purge] subsystem flow rate is 

 [500] scfm.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
[Secondary Containment]

3.6.4.1

General Electric BWR/6 STS 3.6.4.1-1 Rev. 4.0

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],

During operations with a potential for draining the reactor vessel 

(OPDRVs). ]

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. [Secondary containment] 

inoperable [in MODE 1, 

2, or 3].

A.1 Restore [secondary 

containment] to 

OPERABLE status.

4 hours

B. Required Action and 

associated Completion 

Time [of Condition A] not 

met.

B.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

C. [ [Secondary 

containment] inoperable 

during movement of 

[recently] irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

C.1 ---------------NOTE--------------

LCO 3.0.3 is not applicable.

-------------------------------------

Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

AND

C.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately ]
[Secondary Containment]

3.6.4.1

General Electric BWR/6 STS 3.6.4.1-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.4.1.1 [ Verify [secondary containment] vacuum is 

 [0.25] inch of vacuum water gauge.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.6.4.1.2 Verify all [secondary containment] equipment 

hatches are closed and sealed.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.4.1.3 Verify one [secondary containment] access door in 

each access opening is closed, except when the 

access opening is being used for entry and exit.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
[Secondary Containment]

3.6.4.1

General Electric BWR/6 STS 3.6.4.1-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.4.1.4 [ Verify the [secondary containment] can be drawn 

down to  [0.25] inch of vacuum water gauge in 

 [120] seconds using one standby gas treatment 

(SGT) subsystem.

[ [18] months on a 

STAGGERED 

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 

maintained  [0.266] inch of vacuum water gauge 

for 1 hour using one SGT subsystem at a flow rate 

 [4000] cfm.

[ [18] months on a 

STAGGERED 

TEST BASIS for 

each SGT 

subsystem

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SCIVs

3.6.4.2

General Electric BWR/6 STS 3.6.4.2-1 Rev. 4.0

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],

During operations with a potential for draining the reactor vessel 

(OPDRVs).

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 

flow paths with one 

SCIV inoperable.

A.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange.

AND

8 hours
SCIVs

3.6.4.2

General Electric BWR/6 STS 3.6.4.2-2 Rev. 4.0

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 

penetration flow path is 

isolated.

Once per 31 days

B. ------------NOTE------------

Only applicable to 

penetration flow paths 

with two isolation valves.

---------------------------------

One or more penetration 

flow paths with two 

SCIVs inoperable.

B.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange.

4 hours

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 1, 2, 

or 3.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours
SCIVs

3.6.4.2

General Electric BWR/6 STS 3.6.4.2-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition A or B 

not met during 

movement of [recently] 

irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

D.1 ---------------NOTE--------------

LCO 3.0.3 is not applicable.

-------------------------------------

Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

AND

D.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately

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 

valve and blind flange that is not locked, sealed, or 

otherwise secured and is required to be closed 

during accident conditions is closed.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SCIVs

3.6.4.2

General Electric BWR/6 STS 3.6.4.2-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.4.2.2 Verify the isolation time of each power operated, 

automatic SCIV is within limits.

[ In accordance 

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 

position on an actual or simulated automatic 

isolation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SGT System

3.6.4.3

General Electric BWR/6 STS 3.6.4.3-1 Rev. 4.0

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],

During operations with a potential for draining the reactor vessel 

(OPDRVs).

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One SGT subsystem 

inoperable.

A.1 Restore SGT subsystem to 

OPERABLE status.

7 days

B. Required Action and 

associated Completion 

Time of Condition A not 

met in MODE 1, 2, or 3.

B.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

C. Required Action and 

associated Completion 

Time of Condition A not 

met during movement of 

[recently] irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

C.1 Place OPERABLE SGT 

subsystem in operation.

OR

C.2.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

 AND

Immediately

Immediately
SGT System

3.6.4.3

General Electric BWR/6 STS 3.6.4.3-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2.2 Initiate action to suspend 

OPDRVs.

Immediately

D. Two SGT subsystems 

inoperable in MODE 1, 

2, or 3.

D.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

E. Two SGT subsystems 

inoperable during 

movement of [recently] 

irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

E.1 ---------------NOTE--------------

LCO 3.0.3 is not applicable.

-------------------------------------

Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

AND

E.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.4.3.1 Operate each SGT subsystem for  [10] continuous 

hours [with heaters operating].

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
SGT System

3.6.4.3

General Electric BWR/6 STS 3.6.4.3-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.4.3.2 Perform required SGT filter testing in accordance 

with the Ventilation Filter Testing Program (VFTP).

In accordance 

with the VFTP

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual 

or simulated initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.4.3.4 [ Verify each SGT filter cooler bypass damper can 

be opened and the fan started.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

Drywell

3.6.5.1

General Electric BWR/6 STS 3.6.5.1-1 Rev. 4.0

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 

OPERABLE status.

1 hour

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.5.1.1 Verify bypass leakage is less than or equal to the 

bypass leakage limit. However, during the first unit 

startup following bypass leakage testing performed 

in accordance with this SR, the acceptance criterion 

is  [10%] of the drywell bypass leakage limit.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Drywell

3.6.5.1

General Electric BWR/6 STS 3.6.5.1-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.5.1.2 Visually inspect the exposed accessible interior and 

exterior surfaces of the drywell.

[ [40] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Drywell Air Lock

3.6.5.2

General Electric BWR/6 STS 3.6.5.2-1 Rev. 4.0

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 

inoperable.

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

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 

is closed.

AND

A.2 Lock the OPERABLE door 

closed.

AND

A.3 Verify by administrative 

means the OPERABLE 

door is locked closed.

1 hour

24 hours

Once per 31 days
Drywell Air Lock

3.6.5.2

General Electric BWR/6 STS 3.6.5.2-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. Drywell air lock interlock 

mechanism inoperable.

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

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 

is closed.

AND

B.2 Lock an OPERABLE door 

closed.

AND

B.3 Verify by administrative 

means an OPERABLE door 

is locked closed.

1 hour

24 hours

Once per 31 days

C. Drywell air lock 

inoperable for reasons 

other than Condition A 

or B.

C.1 Initiate action to evaluate 

drywell overall leakage rate 

per LCO 3.6.5.1, "Drywell," 

using current air lock test 

results.

AND

C.2 Verify a door is closed.

AND

C.3 Restore air lock to 

OPERABLE status.

Immediately

1 hour

24 hours
Drywell Air Lock

3.6.5.2

General Electric BWR/6 STS 3.6.5.2-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time not met.

D.1 Be in MODE 3.

AND

D.2 Be in MODE 4.

12 hours

36 hours

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 

between the door seals is pressurized to 

 [11.5] psig.

[ 72 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.5.2.2 Verify drywell air lock seal air flask pressure is 

 [90] psig.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Drywell Air Lock

3.6.5.2

General Electric BWR/6 STS 3.6.5.2-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 

opened at a time.

[ 18 months

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 

 [200] scfh by performing an overall air lock 

leakage test at  [11.5] psig.

[ 18 months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.5.2.5 Verify, from an initial pressure of [90] psig, the 

drywell air lock seal pneumatic system pressure 

does not decay at a rate equivalent to > [30] psig for 

a period of [10] days.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Drywell Isolation Valves

3.6.5.3

General Electric BWR/6 STS 3.6.5.3-1 Rev. 4.0

3.6 CONTAINMENT SYSTEMS

3.6.5.3 Drywell Isolation Valve[s]

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 

flow paths with one 

drywell isolation valve 

inoperable.

A.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

blind flange, or check valve 

with flow through the valve 

secured.

AND

8 hours
Drywell Isolation Valves

3.6.5.3

General Electric BWR/6 STS 3.6.5.3-2 Rev. 4.0

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 

penetration flow path is 

isolated.

Prior to entering 

MODE 2 or 3 from 

MODE 4, if not 

performed within the 

previous 92 days

B. ------------NOTE------------

Only applicable to 

penetration flow paths 

with two isolation valves.

---------------------------------

One or more penetration 

flow paths with two 

drywell isolation valves 

inoperable.

B.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

blind flange, or check valve 

with flow through the valve 

secured.

4 hours

C. Required Action and 

associated Completion 

Time not met.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours
Drywell Isolation Valves

3.6.5.3

General Electric BWR/6 STS 3.6.5.3-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.5.3.1 [ Verify each [ ] inch drywell purge isolation valve is 

sealed closed.

[ 31 days

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 

closed.

[ 31 days

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 

flange that is not locked, sealed, or otherwise 

secured and is required to be closed during accident 

conditions is closed.

Prior to entering 

MODE 2 or 3 from 

MODE 4, if not 

performed in the 

previous 92 days
Drywell Isolation Valves

3.6.5.3

General Electric BWR/6 STS 3.6.5.3-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.5.3.4 Verify the isolation time of each power operated, 

automatic drywell isolation valve is within limits.

[ In accordance 

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 

actuates to the isolation position on an actual or 

simulated isolation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.5.3.6 [ Verify each [ ] inch drywell purge isolation valve is 

blocked to restrict the valve from opening > [50]%.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
Drywell Pressure

3.6.5.4

General Electric BWR/6 STS 3.6.5.4-1 Rev. 4.0

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 

containment differential 

pressure not within 

limits.

A.1 Restore drywell-to-primary 

containment differential 

pressure to within limits.

1 hour

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.5.4.1 Verify drywell-to-primary containment differential 

pressure is within limits.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Drywell Air Temperature

3.6.5.5

General Electric BWR/6 STS 3.6.5.5-1 Rev. 4.0

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 

temperature not within 

limit.

A.1 Restore drywell average air 

temperature to within limit.

8 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.5.5.1 Verify drywell average air temperature is within limit. [ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Drywell Vacuum Relief System

3.6.5.6

General Electric BWR/6 STS 3.6.5.6-1 Rev. 4.0

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------------

Separate Condition entry 

is allowed for each 

vacuum relief 

subsystem.

---------------------------------

One or more vacuum 

relief subsystems not 

closed.

A.1 Close the subsystem. 4 hours

B. One or [two] drywell 

post-LOCA vacuum 

relief subsystems 

inoperable for reasons 

other than Condition A.

B.1 Restore drywell post-LOCA 

vacuum relief subsystem(s) 

to OPERABLE status.

30 days

C. One drywell purge 

vacuum relief subsystem 

inoperable for reasons 

other than Condition A.

C.1 Restore drywell purge 

vacuum relief subsystem to 

OPERABLE status.

30 days
Drywell Vacuum Relief System

3.6.5.6

General Electric BWR/6 STS 3.6.5.6-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition B or C 

not met.

D.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

E. [Two] drywell purge 

vacuum relief 

subsystems inoperable 

for reasons other than 

Condition A.

E.1 Restore one drywell purge 

vacuum relief subsystem to 

OPERABLE status.

72 hours

F. [Two] drywell post-LOCA 

vacuum relief 

subsystems inoperable 

for reasons other than 

Condition A.

AND

One drywell purge 

vacuum relief subsystem 

inoperable for reasons 

other than Condition A.

F.1 Restore one drywell postLOCA vacuum relief or 

drywell purge vacuum relief 

subsystem to OPERABLE 

status.

72 hours

G. Required Action and 

associated Completion 

Time of Condition A, E, 

or F not met.

G.1 Be in MODE 3.

AND

G.2 Be in MODE 4.

12 hours

36 hours
Drywell Vacuum Relief System

3.6.5.6

General Electric BWR/6 STS 3.6.5.6-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

H. [Two] drywell purge 

vacuum relief 

subsystems inoperable 

for reasons other than 

Condition A.

AND

One or [two] drywell 

post-LOCA vacuum 

relief subsystems 

inoperable for reasons 

other than Condition A.

H.1 Be in MODE 3.

AND

H.2 Be in MODE 4.

12 hours

36 hours

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 

isolation valve is closed.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Drywell Vacuum Relief System

3.6.5.6

General Electric BWR/6 STS 3.6.5.6-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.5.6.2 Perform a functional test of each vacuum breaker 

and its associated isolation valve.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.6.5.6.3 Verify the opening setpoint of each vacuum breaker 

is  [1.0] psid.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
[SSW] System and [UHS]

3.7.1

General Electric BWR/6 STS 3.7.1-1 Rev. 4.0

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 

towers with one cooling 

tower fan inoperable.

A.1 Restore cooling tower 

fan(s) to OPERABLE 

status.

7 days ]

B. One [SSW] subsystem 

inoperable [for reasons 

other than Condition A].

B.1 --------------NOTES-------------

1. Enter applicable 

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 

to OPERABLE status.

72 hours
[SSW] System and [UHS]

3.7.1

General Electric BWR/6 STS 3.7.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

C.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

-----REVIEWER’S NOTE-----

The [ ]F is the maximum 

allowed UHS temperature 

value and is based on 

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.

D.1 Verify water temperature of 

the UHS is  [90]F 

averaged over the previous 

24 hour period.

Once per hour ]

E. Required Action and 

associated Completion 

Time of Condition D not 

met.

OR

Both [SSW] subsystems 

inoperable [for reasons 

other than Condition A].

[ OR

[UHS] inoperable for 

reasons other than 

Condition A [or D]. ]

E.1 Be in MODE 3.

AND

E.2 Be in MODE 4.

12 hours

36 hours
[SSW] System and [UHS]

3.7.1

General Electric BWR/6 STS 3.7.1-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.1.1 [ Verify the water level of each [UHS] cooling tower 

basin is  [7.25] ft.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.7.1.2 [ Verify the water level [in each SSW pump well of 

the intake structure] is  [ ] ft.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

SR 3.7.1.3 [ Verify the average water temperature of [UHS] is 

 [ ]F.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
[SSW] System and [UHS]

3.7.1

General Electric BWR/6 STS 3.7.1-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.7.1.4 [ Operate each [SSW] cooling tower fan for

 [15] minutes.

[ 31 days

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 

operated, and automatic valve in the flow path 

servicing safety related systems or components, 

that is not locked, sealed, or otherwise secured in 

position, is in the correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.7.1.6 Verify each [SSW] subsystem actuates on an actual 

or simulated initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
HPCS SWS

3.7.2

General Electric BWR/6 STS 3.7.2-1 Rev. 4.0

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 

inoperable.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.2.1 Verify water level of the [a standby service water] 

cooling tower basin is  [7.25] ft.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
HPCS SWS

3.7.2

General Electric BWR/6 STS 3.7.2-2 Rev. 4.0

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, 

and automatic valve in the flow path [servicing 

safety related systems or components], that is not 

locked, sealed, or otherwise secured in position, is 

in the correct position.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.7.2.3 Verify the HPCS SWS actuates on an actual or 

simulated initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
[CRFA] System

3.7.3

General Electric BWR/6 STS 3.7.3-1 Rev. 4.0

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],

During operations with a potential for draining the reactor vessel 

(OPDRVs).

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One [CRFA] subsystem 

inoperable for reasons 

other than Condition B.

A.1 Restore [CRFA] subsystem 

to OPERABLE status.

7 days

B. One or more [CRFA] 

subsystems inoperable 

due to inoperable CRE

boundary in MODE 1, 2, 

or 3.

B.1 Initiate action to implement 

mitigating actions.

AND

B.2 Verify mitigating actions 

ensure CRE occupant 

exposures to radiological, 

chemical, and smoke 

hazards will not exceed 

limits.

AND

B.3 Restore CRE boundary to 

OPERABLE status.

Immediately

24 hours

90 days
[CRFA] System

3.7.3

General Electric BWR/6 STS 3.7.3-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 1, 2, 

or 3.

C.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

D. Required Action and 

associated Completion 

Time of Condition A not 

met during movement of 

[recently] irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

D.1 ---------------NOTE--------------

[ Place in toxic gas 

protection mode if 

automatic transfer to toxic 

gas protection mode is 

inoperable. ]

-------------------------------------

Place OPERABLE [CRFA] 

subsystem in [isolation] 

mode.

OR

D.2.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

 AND

D.2.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately

Immediately
[CRFA] System

3.7.3

General Electric BWR/6 STS 3.7.3-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. Two [CRFA] subsystems 

inoperable in MODE 1, 

2, or 3 for reasons other 

than Condition B.

E.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3.

I

12 hours

F. Two [CRFA] subsystems 

inoperable during 

movement of [recently] 

irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

OR

One or more [CRFA] 

subsystems inoperable 

due to inoperable CRE 

boundary during 

movement of [recently] 

irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

F.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

AND

F.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately
[CRFA] System

3.7.3

General Electric BWR/6 STS 3.7.3-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.3.1 Operate each [CRFA] subsystem for [ 10 

continuous hours with the heaters operating or (for 

systems without heaters)  15 minutes].

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.7.3.2 Perform required [CRFA] filter testing in accordance 

with the [Ventilation Filter Testing Program (VFTP)].

In accordance 

with the [VFTP]

SR 3.7.3.3 Verify each [CRFA] subsystem actuates on an 

actual or simulated initiation signal.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.7.3.4 Perform required CRE unfiltered air inleakage 

testing in accordance with the Control Room 

Envelope Habitability Program.

In accordance 

with the Control 

Room Envelope 

Habitability 

Program
[Control Room AC] System

3.7.4

General Electric BWR/6 STS 3.7.4-1 Rev. 4.0

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],

During operations with a potential for draining the reactor vessel 

(OPDRVs).

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One [control room AC] 

subsystem inoperable.

A.1 Restore [control room AC] 

subsystem to OPERABLE 

status.

30 days

B. Two [control room AC] 

subsystems inoperable.

B.1 Verify control room area 

temperature < [90]°F.

AND

B.2 Restore one [control room 

AC] subsystem to 

OPERABLE status.

Once per 4 hours

7 days

C. Required Action and 

associated Completion 

Time of Condition A not 

met in MODE 1, 2, or 3.

C.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours
[Control Room AC] System

3.7.4

General Electric BWR/6 STS 3.7.4-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition A not 

met during movement of 

[recently] irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

D.1 Place OPERABLE [control 

room AC] subsystem in 

operation.

OR

D.2.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

 AND

D.2.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately

Immediately

E. Required Action and 

associated Completion 

Time of Condition B not 

met during movement of 

[recently] irradiated fuel 

assemblies in the 

[primary or secondary 

containment] or during 

OPDRVs.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

E.1 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary 

containment].

AND

E.2 Initiate action to suspend 

OPDRVs.

Immediately

Immediately
[Control Room AC] System

3.7.4

General Electric BWR/6 STS 3.7.4-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.4.1 Verify each [control room AC] subsystem has the 

capability to remove the assumed heat load.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Main Condenser Offgas

3.7.5

General Electric BWR/6 STS 3.7.5-1 Rev. 4.0

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 

rate of the noble gases 

not within limit.

A.1 Restore gross gamma 

activity rate of the noble 

gases to within limit.

72 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 [ Isolate all main steam 

lines.

OR

B.2 Isolate SJAE.

OR

B.3 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3.

12 hours ]

12 hours

12 hours
Main Condenser Offgas

3.7.5

General Electric BWR/6 STS 3.7.5-2 Rev. 4.0

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 

gases is  [380] mCi/second [after decay of 

30 minutes].

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

AND

Once within 

4 hours after a 

 50% increase in 

the nominal 

steady state 

fission gas 

release after 

factoring out 

increases due to 

changes in 

THERMAL 

POWER level
Main Turbine Bypass System

3.7.6

General Electric BWR/6 STS 3.7.6-1 Rev. 4.0

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 

LCO not met or Main

Turbine Bypass System 

inoperable.]

A.1 [Satisfy the requirements of 

the LCO or restore Main 

Turbine Bypass System to 

OPERABLE status.]

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours
Main Turbine Bypass System

3.7.6

General Electric BWR/6 STS 3.7.6-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.6.1 Verify one complete cycle of each main turbine

bypass valve.

[ 31 days

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 

RESPONSE TIME is within limits.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Fuel Pool Water Level

3.7.7

General Electric BWR/6 STS 3.7.7-1 Rev. 4.0

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 

within limit.

A.1 ---------------NOTE--------------

LCO 3.0.3 is not applicable.

-------------------------------------

Suspend movement of 

irradiated fuel assemblies in 

the associated fuel storage 

pool(s).

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.7.1 Verify the fuel pool water level is  [23] ft over the 

top of irradiated fuel assemblies seated in the 

storage racks.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-1 Rev. 4.0

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 

circuit inoperable.

A.1 Perform SR 3.8.1.1 for 

OPERABLE [required] 

offsite circuit.

AND

1 hour

AND

Once per 8 hours 

thereafter
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2 Declare required feature(s) 

with no offsite power 

available inoperable when 

the redundant required 

feature(s) are inoperable.

AND

A.3 Restore [required] offsite 

circuit to OPERABLE 

status.

24 hours from 

discovery of no offsite 

power to one division 

concurrent with 

inoperability of 

redundant required 

feature(s)

72 hours

AND

24 hours from 

discovery of two

divisions with no 

offsite power

B. One [required] DG 

inoperable.

B.1 Perform SR 3.8.1.1 for 

OPERABLE [required] 

offsite circuit(s).

AND

B.2 Declare required feature(s), 

supported by the inoperable 

DG, inoperable when the 

redundant required 

feature(s) are inoperable.

AND

1 hour

AND

Once per 8 hours 

thereafter

4 hours from 

discovery of 

Condition B 

concurrent with 

inoperability of 

redundant required 

feature(s)
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.3.1 Determine OPERABLE 

DG(s) are not inoperable 

due to common cause 

failure.

 OR

B.3.2 Perform SR 3.8.1.2 for 

OPERABLE DG(s).

AND

B.4 Restore required DG to 

OPERABLE status.

[24] hours

[24] hours

72 hours

C. Two [required] offsite 

circuits inoperable.

C.1 Declare required feature(s) 

inoperable when the 

redundant required 

feature(s) are inoperable.

AND

C.2 Restore one [required] 

offsite circuit to OPERABLE 

status.

12 hours from 

discovery of 

Condition C 

concurrent with 

inoperability of 

redundant required 

feature(s)

24 hours
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-4 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. One [required] offsite 

circuit inoperable.

AND

One [required] DG 

inoperable.

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

Enter applicable Conditions and 

Required Actions of LCO 3.8.9, 

"Distribution Systems - Operating," 

when Condition D is entered with no 

AC power source to any [division].

------------------------------------------------

D.1 Restore [required] offsite 

circuit to OPERABLE 

status.

OR

D.2 Restore [required] DG to 

OPERABLE status.

12 hours

12 hours

E. Two [required] DGs 

inoperable.

E.1 Restore one [required] DG 

to OPERABLE status.

2 hours

OR

24 hours if Division 3 

DG is inoperable

F. [ One [required] 

[automatic load 

sequencer] inoperable.

----------REVIEWER’S NOTE----------

This Condition may be deleted if the 

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] 

[automatic load sequencer] 

to OPERABLE status.

[12] hours ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-5 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

G. Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, E, or [F] not met.

G.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

H. Three or more [required] 

AC sources inoperable.

H.1 Enter LCO 3.0.3. Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.1.1 Verify correct breaker alignment and indicated 

power availability for each [required] offsite circuit.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-6 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

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 

achieves steady state voltage  [3744] V 

and  [4576] V and frequency  [58.8] Hz 

and  [61.2] Hz.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-7 Rev. 4.0

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 

operates for  60 minutes at a load  [5450] kW and 

 [5740] kW for [Division 1 and 2] DGs, and 

 [3300] kW and  [3500] kW for [Division 3] DG.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.8.1.4 Verify each day tank [and engine mounted tank] 

contains  [220] gal of fuel oil for [Divisions 1 and 2] 

and  [220] gal for [Division 3].

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-8 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.1.5 Check for and remove accumulated water from each 

day tank [and engine mounted tank].

[ [31] days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.8.1.6 Verify the fuel oil transfer system operates to 

[automatically] transfer fuel oil from storage tank[s] 

to the day tank [and engine mounted tank].

[ [92] days

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 

achieves:

a. In  [10] seconds, voltage  [3744] V and 

frequency  [58.8] Hz and

b. Steady state voltage  [3744] V and  [4576] V 

and frequency  [58.8] Hz and  [61.2] Hz.

[ 184 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-9 Rev. 4.0

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 

power supply] from the [normal offsite circuit to each 

[required] alternate offsite circuit and between the 

[required] alternate] offsite circuits.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-10 Rev. 4.0

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 

to its associated single largest post-accident load for 

[Division 1 and  [550] kW for Division 2] DGs and 

 [2180] kW for [Division 3] DG, and:

a. Following load rejection, the frequency is 

 [69] Hz,

b. Within [3] seconds following load rejection, the 

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.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-11 Rev. 4.0

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 

maintained  [5000] V during and following a load 

rejection of a load  [5450] kW and  [5740] kW for 

[Division 1 and 2] DGs and  [3300] kW and 

 [3500] kW for [Division 3] DG.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-12 Rev. 4.0

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 

signal:

a. De-energization of emergency buses,

b. Load shedding from emergency buses, and

c. DG auto-starts from standby condition and:

1. Energizes permanently connected loads 

in  [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.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-13 Rev. 4.0

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 

Cooling System (ECCS) initiation signal each DG 

auto-starts from standby condition and:

a. In  [10] seconds after auto-start and during 

tests, achieves voltage  [3744] V frequency 

 [58.8] Hz

b. Achieves steady state voltage  [3744] V and 

 [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 autoconnected through the automatic load 

sequencer] to from the offsite power system.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-14 Rev. 4.0

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 

bypassed on [actual or simulated loss of voltage 

signal on the emergency bus concurrent with an 

actual or simulated ECCS initiation signal].

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-15 Rev. 4.0

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 hours:

a. For  [2] hours loaded,  [5450] kW and 

 [5740] kW for Division 1 and 2 DGs, 

 [3630] kW and  [3830] kW for Division 3 DG 

and

b. For the remaining hours of the test loaded 

 [3744] kW and  [4576] kW for Division 1 

and 2 DGs, and  [3300] kW and  [3500] kW 

for Division 3 DG.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-16 Rev. 4.0

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:

a. In  [10] seconds, voltage  [3744] V and 

frequency  [58.8] Hz and

b. Steady state voltage  [3744] V and  [4576] V 

and frequency  [58.8] Hz and  [61.2] Hz.

[ [18] months

OR

In accordance 

with the

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:

a. Synchronizes with offsite power source while 

loaded with emergency loads upon a simulated 

restoration of offsite power,

b. Transfers loads to offsite power source, and

c. Returns to ready-to-load operation.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-17 Rev. 4.0

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 

connected to its bus, an actual or simulated ECCS 

initiation signal overrides the test mode by:

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

[ b. Automatically energizing the emergency load 

from offsite power. ]

[ [18] months

OR

In accordance 

with the

Surveillance 

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 

is within ± [10% of design interval] [for each load 

sequencer timer].

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-18 Rev. 4.0

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 

power signal in conjunction with an actual or 

simulated ECCS initiation signal:

a. De-energization of emergency buses,

b. Load shedding from emergency buses, and

c. DG auto-starts from standby condition and:

1. Energizes permanently connected loads 

in  [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.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
AC Sources - Operating

3.8.1

General Electric BWR/6 STS 3.8.1-19 Rev. 4.0

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 

condition, [each] [Division 1, 2, and 3] DG achieves:

a. In  [10] seconds, voltage  [3744] V and 

frequency  [58.8] Hz and

b. Steady state voltage  [3744] V and  [4576] V 

and frequency  [58.8] Hz and  [61.2] Hz.

[ 10 years

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

AC Sources - Shutdown

3.8.2

General Electric BWR/6 STS 3.8.2-1 Rev. 4.0

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.
AC Sources - Shutdown

3.8.2

General Electric BWR/6 STS 3.8.2-2 Rev. 4.0

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 deenergized as a result of 

Condition A.

------------------------------------------------

A.1 Declare affected required 

feature(s) with no offsite 

power available inoperable.

OR

A.2.1 Suspend CORE 

ALTERATIONS.

 AND

A.2.2 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

and secondary] 

containment.

 AND

A.2.3 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel (OPDRVs).

 AND

A.2.4 Initiate action to restore 

required offsite power 

circuit to OPERABLE 

status.

Immediately

Immediately

Immediately

Immediately

Immediately
AC Sources - Shutdown

3.8.2

General Electric BWR/6 STS 3.8.2-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. LCO Item b. not met. B.1 Suspend CORE 

ALTERATIONS.

AND

B.2 Suspend movement of 

[recently] irradiated fuel 

assemblies in [primary and 

secondary] containment.

AND

B.3 Initiate action to suspend 

OPDRVs.

AND

B.4 Initiate action to restore 

required DG to OPERABLE 

status.

Immediately

Immediately

Immediately

Immediately

C. LCO Item c. not met. C.1 Declare HPCS [and 2C 

Standby Service Water

System] inoperable.

[72] hours
AC Sources - Shutdown

3.8.2

General Electric BWR/6 STS 3.8.2-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.2.1 ------------------------------NOTES-----------------------------

1. The following SRs are not required to be 

performed: SR 3.8.1.3, SR 3.8.1.9 through 

SR 3.8.1.11, SR 3.8.1.13 through SR 3.8.1.16, 

[SR 3.8.1.18], and SR 3.8.1.19.

2. SR 3.8.1.12 and SR 3.8.1.19 are not required to 

be met when associated ECCS subsystem(s) 

are not required to be OPERABLE per 

LCO 3.5.2, "ECCS-Shutdown."

---------------------------------------------------------------------

For AC sources required to be OPERABLE, the SRs 

of Specification 3.8.1, except SR 3.8.1.8, 

SR 3.8.1.17, and SR 3.8.1.20, are applicable.

In accordance 

with applicable 

SRs
Diesel Fuel Oil, Lube Oil, and Starting Air

3.8.3

General Electric BWR/6 STS 3.8.3-1 Rev. 4.0

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 

fuel oil level less than a 

[7] day supply and 

greater than a [6] day 

supply.

A.1 Restore fuel oil level to 

within limits.

48 hours

B. One or more DGs with 

lube oil inventory less 

than a [7] day supply 

and greater than a 

[6] day supply.

B.1 Restore lube oil inventory to 

within limits.

48 hours

C. One or more DGs with 

stored fuel oil total 

particulates not within 

limit.

C.1 Restore fuel oil total 

particulates to within limit.

7 days

D. One or more DGs with 

new fuel oil properties 

not within limits.

D.1 Restore stored fuel oil 

properties to within limits.

30 days
Diesel Fuel Oil, Lube Oil, and Starting Air

3.8.3

General Electric BWR/6 STS 3.8.3-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. One or more DGs with 

starting air receiver 

pressure < [225] psig 

and  [125] psig.

E.1 Restore starting air receiver 

pressure to  [225] psig.

48 hours

F. Required Actions and 

associated Completion 

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.

F.1 Declare associated DG 

inoperable.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.3.1 Verify each fuel oil storage tank contains ≥ a [7] day 

supply of fuel.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Diesel Fuel Oil, Lube Oil, and Starting Air

3.8.3

General Electric BWR/6 STS 3.8.3-3 Rev. 4.0

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 

are tested in accordance with, and maintained within 

the limits of, the Diesel Fuel Oil Testing Program.

In accordance 

with the Diesel 

Fuel Oil Testing 

Program

SR 3.8.3.4 Verify each DG air start receiver pressure is 

 [225] psig.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.8.3.5 Check for and remove accumulated water from each 

fuel oil storage tank.

[ [31] days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

DC Sources - Operating

3.8.4

General Electric BWR/6 STS 3.8.4-1 Rev. 4.0

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 

charger[s] on one 

subsystem inoperable.

A.1 Restore battery terminal 

voltage to greater than or 

equal to the minimum 

established float voltage.

AND

A.2 Verify battery float current 

 [2] amps.

AND

A. 3 Restore battery charger[s] 

to OPERABLE status.

2 hours

Once per [12] hours

[72] hours

[B. One [or two] batter[y][ies 

on one subsystem] 

inoperable.

B.1 Restore batter[y][ies] to 

OPERABLE status.

[2] hours ]

C. [Division 1 or 2] DC 

electrical power 

subsystem inoperable 

for reasons other than 

Condition A [or B].

C.1 Restore [Division 1 and 2] 

DC electrical power 

subsystems to OPERABLE 

status.

[2] hours
DC Sources - Operating

3.8.4

General Electric BWR/6 STS 3.8.4-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time for [Division 1 or 2] 

DC electrical power 

subsystem for 

Condition A, B, or C not 

met.

D.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

E. [Division 3] DC electrical 

power subsystem 

inoperable for reasons 

other than Condition A 

[or B].

E.1 Declare High Pressure 

Core Spray System 

[and 2C Standby Service 

Water System] inoperable.

Immediately

F. Required Action and 

associated Completion 

Time for [Division 3] DC 

electrical power 

subsystem for 

Condition A, B, or E not 

met.

F.1 Be in MODE 3.

AND

F.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.4.1 Verify battery terminal voltage is greater than or 

equal to the minimum established float voltage.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
DC Sources - Operating

3.8.4

General Electric BWR/6 STS 3.8.4-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.4.2 Verify each [required] battery charger 

supplies [400] amps at greater than or equal to the 

minimum established float voltage for  [8] hours.

OR

Verify each battery charger can recharge the battery 

to the fully charged state within [24] hours while 

supplying the largest combined demands of the 

various continuous steady state loads, after a 

battery discharge to the bounding design basis 

event discharge state.

[ [18 months

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

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 

maintain in OPERABLE status, the required 

emergency loads for the design duty cycle when 

subjected to a battery service test.

[ [18] months

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

DC Sources - Shutdown

3.8.5

General Electric BWR/6 STS 3.8.5-1 Rev. 4.0

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 

charger[s on one 

subsystem] inoperable.

AND

The redundant 

subsystem battery and 

charger[s] OPERABLE.

A.1 Restore battery terminal 

voltage to greater than or 

equal to the minimum 

established float voltage.

AND

A.2 Verify battery float current 

 [2] amps.

AND

2 hours

Once per [12] hours
DC Sources - Shutdown

3.8.5

General Electric BWR/6 STS 3.8.5-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.3 Restore battery charger[s] 

to OPERABLE status.

[72] hours ]

B. One [or more] required 

DC electrical power 

subsystem[s] inoperable 

[for reasons other than 

Condition A.

OR

Required Action and 

associated Completion 

Time of Condition A not 

met.]

B.1 Declare affected required 

feature(s) inoperable.

OR

B.2.1 Suspend CORE 

ALTERATIONS.

 AND

B.2.2 Suspend movement of 

[recently] irradiated fuel 

assemblies in the [primary 

or secondary] containment.

 AND

B.2.3 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel.

 AND

B.2.4 Initiate action to restore 

required DC electrical 

power subsystems to 

OPERABLE status.

Immediately

Immediately

Immediately

Immediately

Immediately
DC Sources - Shutdown

3.8.5

General Electric BWR/6 STS 3.8.5-3 Rev. 4.0

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 

following SRs are applicable:

SR 3.8.4.1

SR 3.8.4.2

SR 3.8.4.3

In accordance 

with applicable 

SRs

Battery Parameters

3.8.6

General Electric BWR/6 STS 3.8.6-1 Rev. 4.0

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 

on one subsystem] with 

one or more battery cells 

float voltage < [2.07] V.

A.1 Perform SR 3.8.4.1.

AND

A.2 Perform SR 3.8.6.1.

AND

A.3 Restore affected cell 

voltage  [2.07] V.

2 hours

2 hours

24 hours

B. One [or two] batter[y][ies 

on one subsystem] with 

float current > [2] amps.

B.1 Perform SR 3.8.4.1.

AND

B.2 Restore battery float current 

to  [2] amps.

2 hours

[12] hours
Battery Parameters

3.8.6

General Electric BWR/6 STS 3.8.6-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. ------------NOTE------------

Required Action C.2 

shall be completed if 

electrolyte level was 

below the top of plates.

---------------------------------

One [or two] batter[y][ies 

on one subsystem] with 

one or more cells 

electrolyte level less 

than minimum 

established design 

limits.

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

Required Actions C.1 and C.2 are 

only applicable if electrolyte level 

was below the top of plates.

------------------------------------------------

C.1 Restore electrolyte level to 

above top of plates.

AND

C.2 Verify no evidence of 

leakage.

AND

C.3 Restore electrolyte level to 

greater than or equal to 

minimum established 

design limits.

8 hours

12 hours

31 days

D. One [or two] batter[y][ies 

on one subsystem] with 

pilot cell electrolyte 

temperature less than 

minimum established 

design limits.

D.1 Restore battery pilot cell 

temperature to greater than 

or equal to minimum 

established design limits.

12 hours

E. One or more batteries in 

redundant subsystems

with battery parameters 

not within limits.

E.1 Restore battery parameters 

for batteries in one 

subsystem to within limits.

2 hours
Battery Parameters

3.8.6

General Electric BWR/6 STS 3.8.6-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F. Required Action and 

associated Completion 

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.

F.1 Declare associated battery 

inoperable.

Immediately

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 ]
Battery Parameters

3.8.6

General Electric BWR/6 STS 3.8.6-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.6.2 Verify each battery pilot cell float voltage is 

 [2.07] V.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.8.6.3 Verify each battery connected cell electrolyte level is 

greater than or equal to minimum established 

design limits.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.8.6.4 Verify each battery pilot cell temperature is greater 

than or equal to minimum established design limits.

[ 31 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.8.6.5 Verify each battery connected cell float voltage is 

 [2.07] V.

[ 92 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Battery Parameters

3.8.6

General Electric BWR/6 STS 3.8.6-5 Rev. 4.0

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 

manufacturer's rating when subjected to a 

performance discharge test or a modified 

performance discharge test.

[ 60 months

OR

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

Inverters - Operating

3.8.7

General Electric BWR/6 STS 3.8.7-1 Rev. 4.0

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 

inoperable.

A.1 ---------------NOTE--------------

Enter applicable Conditions 

and Required Actions of 

LCO 3.8.9, "Distribution 

Systems - Operating" with 

any AC vital bus deenergized.

-------------------------------------

Restore [Division 1 and 2] 

inverters to OPERABLE 

status.

24 hours
Inverters - Operating

3.8.7

General Electric BWR/6 STS 3.8.7-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

C. [ [Division 3] inverter 

inoperable.

C.1 Declare High Pressure 

Core Spray System [and 

2C Standby Service Water 

System] inoperable.

Immediately ]

D. Required Action and 

associated Completion 

Time of Condition C not 

met.

D.1 Be in MODE 3.

AND

D.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.7.1 Verify correct inverter voltage, [frequency,] and 

alignment to required AC vital buses.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Inverters - Shutdown

3.8.8

General Electric BWR/6 STS 3.8.8-1 Rev. 4.0

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] 

inverter[s] inoperable.

A.1 Declare affected required 

feature(s) inoperable.

OR

A.2.1 Suspend CORE 

ALTERATIONS.

 AND

Immediately

Immediately
Inverters - Shutdown

3.8.8

General Electric BWR/6 STS 3.8.8-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2.2 Suspend handling of 

[recently] irradiated fuel 

assemblies in the [primary 

or secondary] containment.

 AND

A.2.3 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel.

 AND

A.2.4 Initiate action to restore 

required inverters to 

OPERABLE status.

Immediately

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.8.1 Verify correct inverter voltage, [frequency,] and 

alignments to [required] AC vital buses.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Distribution Systems - Operating

3.8.9

General Electric BWR/6 STS 3.8.9-1 Rev. 4.0

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 

and 2] AC electrical 

power distribution 

subsystems inoperable.

A.1 ---------------NOTE--------------

Enter applicable Conditions 

and Required Actions of 

LCO 3.8.4, "DC Sources -

Operating," for DC trains 

made inoperable by 

inoperable power 

distribution subsystems.

-------------------------------------

Restore [Division 1 and 2] 

AC electrical power 

distribution subsystem(s) to 

OPERABLE status.

8 hours

B. [ One or more [Division 1 

and 2] AC vital buses 

inoperable.

B.1 Restore [Division 1 and 2] 

AC vital bus distribution 

subsystem(s) to 

OPERABLE status.

2 hours ]

C. One or more [Division 1 

and 2] DC electrical 

power distribution 

subsystems inoperable.

C.1 Restore [Division 1 and 2] 

DC electrical power 

distribution subsystem(s) to 

OPERABLE status.

2 hours
Distribution Systems - Operating

3.8.9

General Electric BWR/6 STS 3.8.9-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition A, B, 

or C not met.

D.1 ---------------NOTE--------------

LCO 3.0.4.a is not 

applicable when entering 

MODE 3.

-------------------------------------

Be in MODE 3. 12 hours

E. One or more [Division 3] 

AC, DC, or AC vital bus 

electrical power 

distribution subsystems 

inoperable.

E.1 Declare High Pressure 

Core Spray System [and 

2C Standby Service Water 

System] inoperable.

Immediately

F. Two or more electrical 

power distribution 

subsystems inoperable 

that result in a loss of 

function.

F.1 Enter LCO 3.0.3. Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.9.1 Verify correct breaker alignments and voltage to 

[required] AC, DC, [and AC vital bus] electrical 

power distribution subsystems.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Distribution Systems - Shutdown

3.8.10

General Electric BWR/6 STS 3.8.10-1 Rev. 4.0

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 

AC, DC, [or AC vital bus] 

electrical power 

distribution subsystems 

inoperable.

A.1 Declare associated 

supported required 

feature(s) inoperable.

OR

A.2.1 Suspend CORE 

ALTERATIONS.

 AND

A.2.2 Suspend handling of 

[recently] irradiated fuel 

assemblies in the [primary 

or secondary] containment.

 AND

Immediately

Immediately

Immediately
Distribution Systems - Shutdown

3.8.10

General Electric BWR/6 STS 3.8.10-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2.3 Initiate action to suspend 

operations with a potential 

for draining the reactor 

vessel.

 AND

A.2.4 Initiate actions to restore 

[required] AC, DC, [and AC 

vital bus] electrical power 

distribution subsystems to 

OPERABLE status.

 AND

A.2.5 Declare associated 

required shutdown cooling 

subsystem(s) inoperable 

and not in operation.

Immediately

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.10.1 Verify correct breaker alignments and voltage to 

[required] AC, DC, [and AC vital bus] electrical 

power distribution subsystems.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Refueling Equipment Interlocks

3.9.1

General Electric BWR/6 STS 3.9.1-1 Rev. 4.0

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 

refueling equipment 

interlocks inoperable.

A.1 Suspend in-vessel fuel 

movement with equipment 

associated with the 

inoperable interlock(s).

OR

A.2.1 Insert a control rod 

withdrawal block.

AND

A.2.2 Verify all control rods are 

fully inserted.

Immediately

Immediately

Immediately
Refueling Equipment Interlocks

3.9.1

General Electric BWR/6 STS 3.9.1-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of 

the following required refueling equipment interlock 

inputs:

a. All-rods-in,

b. Refuel platform position, and

c. Refuel platform [main] hoist, fuel loaded.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Refuel Position One-Rod-Out Interlock

3.9.2

General Electric BWR/6 STS 3.9.2-1 Rev. 4.0

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-rodout interlock inoperable.A.1 Suspend control rod 

withdrawal.

AND

A.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.2.1 Verify reactor mode switch locked in refuel position. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Refuel Position One-Rod-Out Interlock

3.9.2

General Electric BWR/6 STS 3.9.2-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.9.2.2 -------------------------------NOTE------------------------------

Not required to be performed until 1 hour after any 

control rod is withdrawn.

---------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. [ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Control Rod Position

3.9.3

General Electric BWR/6 STS 3.9.3-1 Rev. 4.0

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 

rods not fully inserted.

A.1 Suspend loading fuel 

assemblies into the core.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.3.1 Verify all control rods are fully inserted. [ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Control Rod Position Indication

3.9.4

General Electric BWR/6 STS 3.9.4-1 Rev. 4.0

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 

control rod position 

indication channels 

inoperable.

A.1.1 Suspend in-vessel fuel 

movement.

 AND

A.1.2 Suspend control rod 

withdrawal.

 AND

A.1.3 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

OR

A.2.1 Initiate action to fully insert 

the control rod associated 

with the inoperable position 

indicator.

 AND

Immediately

Immediately

Immediately

Immediately
Control Rod Position Indication

3.9.4

General Electric BWR/6 STS 3.9.4-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2.2 Initiate action to disarm the 

control rod drive associated 

with the fully inserted 

control rod.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.4.1 Verify the required channel has no "full-in" indication 

on each control rod that is not "full-in."

Each time the 

control rod is 

withdrawn from 

the "full-in" 

position
Control Rod OPERABILITY - Refueling

3.9.5

General Electric BWR/6 STS 3.9.5-1 Rev. 4.0

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 

control rods inoperable.

A.1 Initiate action to fully insert 

inoperable withdrawn 

control rods.

Immediately

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 ]
Control Rod OPERABILITY - Refueling

3.9.5

General Electric BWR/6 STS 3.9.5-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.9.5.2 Verify each withdrawn control rod scram 

accumulator pressure is  [1520] psig.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
[RPV] Water Level - [Irradiated Fuel]

3.9.6

General Electric BWR/6 STS 3.9.6-1 Rev. 4.0

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 

within limit.

A.1 Suspend movement of fuel 

assemblies and handling of 

control rods within the 

[RPV].

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.6.1 Verify [RPV] water level is  [22 ft 8 inches] above 

the top of the [RPV flange].

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

[RPV] Water Level - New Fuel or Control Rods

3.9.7

General Electric BWR/6 STS 3.9.7-1 Rev. 4.0

[ 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 

within limit.

A.1 Suspend movement of fuel 

assemblies and handling of 

control rods within the 

[RPV].

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.7.1 Verify [RPV] water level is  [22 ft 8 inches] above 

the top of irradiated fuel assemblies seated within 

the [RPV].

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control 

Program ] ]

RHR - High Water Level

3.9.8

General Electric BWR/6 STS 3.9.8-1 Rev. 4.0

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 hours per 8 hour 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 

cooling subsystem 

inoperable.

A.1 Verify an alternate method 

of decay heat removal is 

available.

1 hour

AND

Once per 24 hours 

thereafter

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Suspend loading irradiated 

fuel assemblies into the 

RPV.

AND

B.2 Initiate action to restore 

[primary or secondary] 

containment to OPERABLE 

status.

AND

Immediately

Immediately
RHR - High Water Level

3.9.8

General Electric BWR/6 STS 3.9.8-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.3 Initiate action to restore one 

standby gas treatment 

subsystem to OPERABLE 

status.

AND

B.4 Initiate action to restore 

isolation capability in each 

required secondary 

containment penetration 

flow path not isolated.

Immediately

Immediately

C. No RHR shutdown 

cooling subsystem in 

operation.

C.1 Verify reactor coolant 

circulation by an alternate 

method.

AND

C.2 Monitor reactor coolant 

temperature.

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per

12 hours

thereafter

Once per hour
RHR - High Water Level

3.9.8

General Electric BWR/6 STS 3.9.8-3 Rev. 4.0

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 

operating.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

RHR - Low Water Level

3.9.9

General Electric BWR/6 STS 3.9.9-1 Rev. 4.0

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 hours per 8 hour 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 

shutdown cooling 

subsystems inoperable.

A.1 Verify an alternate method 

of decay heat removal is 

available for each 

inoperable RHR shutdown 

cooling subsystem.

1 hour

AND

Once per 24 hours 

thereafter

B. Required Action and 

associated Completion 

Time of Condition A not 

met.

B.1 Initiate action to restore 

[primary or secondary] 

containment to OPERABLE 

status.

AND

B.2 Initiate action to restore one 

standby gas treatment 

subsystem to OPERABLE 

status.

AND

Immediately

Immediately
RHR - Low Water Level

3.9.9

General Electric BWR/6 STS 3.9.9-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.3 Initiate action to restore 

isolation capability in each 

required secondary 

containment penetration 

flow path not isolated.

Immediately

C. No RHR shutdown 

cooling subsystem in 

operation.

C.1 Verify reactor coolant 

circulation by an alternate 

method.

AND

C.2 Monitor reactor coolant 

temperature.

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per 12 hours 

thereafter

Once per hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.9.1 Verify one RHR shutdown cooling subsystem is 

operating.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Inservice Leak and Hydrostatic Testing Operation

3.10.1

General Electric BWR/6 STS 3.10.1-1 Rev. 4.0

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.
Inservice Leak and Hydrostatic Testing Operation

3.10.1

General Electric BWR/6 STS 3.10.1-2 Rev. 4.0

ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the 

above requirements not 

met.

A.1 ---------------NOTE--------------

Required Actions to be in 

MODE 4 include reducing 

average reactor coolant 

temperature to  [200]F.

-------------------------------------

Enter the applicable 

Condition of the affected 

LCO.

OR

A.2.1 Suspend activities that 

could increase the average 

reactor coolant temperature 

or pressure.

 AND

A.2.2 Reduce average reactor 

coolant temperature to 

 [200]F.

Immediately

Immediately

24 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.1.1 Perform the applicable SRs for the required 

MODE 3 LCOs.

According to the 

applicable SRs
Reactor Mode Switch Interlock Testing

3.10.2

General Electric BWR/6 STS 3.10.2-1 Rev. 4.0

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 

above requirements not 

met.

A.1 Suspend CORE 

ALTERATIONS except for 

control rod insertion.

AND

A.2 Fully insert all insertable 

control rods in core cells 

containing one or more fuel 

assemblies.

AND

A.3.1 Place the reactor mode 

switch in the shutdown 

position.

 OR

Immediately

1 hour

1 hour
Reactor Mode Switch Interlock Testing

3.10.2

General Electric BWR/6 STS 3.10.2-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.3.2 ---------------NOTE--------------

Only applicable in MODE 5.

-------------------------------------

Place the reactor mode 

switch in the refuel position.

1 hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.2.1 Verify all control rods are fully inserted in core cells 

containing one or more fuel assemblies.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. [ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Single Control Rod Withdrawal - Hot Shutdown

3.10.3

General Electric BWR/6 STS 3.10.3-1 Rev. 4.0

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.
Single Control Rod Withdrawal - Hot Shutdown

3.10.3

General Electric BWR/6 STS 3.10.3-2 Rev. 4.0

ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the 

above requirements not 

met.

A.1 --------------NOTES-------------

1. Required Actions to fully 

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 

Condition of the affected 

LCO.

OR

A.2.1 Initiate action to fully insert 

all insertable control rods.

 AND

A.2.2 Place the reactor mode 

switch in the shutdown 

position.

Immediately

Immediately

1 hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the 

applicable SRs
Single Control Rod Withdrawal - Hot Shutdown

3.10.3

General Electric BWR/6 STS 3.10.3-3 Rev. 4.0

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 

being withdrawn, in a five by five array centered on 

the control rod being withdrawn, are disarmed.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.3.3 Verify all control rods, other than the control rod 

being withdrawn, are fully inserted.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Single Control Rod Withdrawal - Cold Shutdown

3.10.4

General Electric BWR/6 STS 3.10.4-1 Rev. 4.0

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.
Single Control Rod Withdrawal - Cold Shutdown

3.10.4

General Electric BWR/6 STS 3.10.4-2 Rev. 4.0

ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the 

above requirements not 

met with the affected 

control rod insertable.

A.1 --------------NOTES-------------

1. Required Actions to fully 

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 

Condition of the affected 

LCO.

OR

A.2.1 Initiate action to fully insert 

all insertable control rods.

 AND

A.2.2 Place the reactor mode 

switch in the shutdown 

position.

Immediately

Immediately

1 hour

B. One or more of the 

above requirements not 

met with the affected 

control rod not 

insertable.

B.1 Suspend withdrawal of the 

control rod and removal of 

associated CRD.

AND

B.2.1 Initiate action to fully insert 

all control rods.

 OR

Immediately

Immediately
Single Control Rod Withdrawal - Cold Shutdown

3.10.4

General Electric BWR/6 STS 3.10.4-3 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2.2 Initiate action to satisfy the 

requirements of this LCO.

Immediately

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 

being withdrawn, in a five by five array centered on 

the control rod being withdrawn, are disarmed.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.4.3 Verify all control rods, other than the control rod 

being withdrawn, are fully inserted.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Single Control Rod Withdrawal - Cold Shutdown

3.10.4

General Electric BWR/6 STS 3.10.4-4 Rev. 4.0

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 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Single CRD Removal - Refueling

3.10.5

General Electric BWR/6 STS 3.10.5-1 Rev. 4.0

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 

above requirements not 

met.

A.1 Suspend removal of the 

CRD mechanism.

AND

A.2.1 Initiate action to fully inset 

all control rods.

 OR

Immediately

Immediately
Single CRD Removal - Refueling

3.10.5

General Electric BWR/6 STS 3.10.5-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2.2 Initiate action to satisfy the 

requirements of this LCO.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.5.1 Verify all controls rods, other than the control rod 

withdrawn for the removal of the associated CRD, 

are fully inserted.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.5.2 Verify all control rods, other than the control rod 

withdrawn for the removal of the associated CRD, in 

a five by five array centered on the control rod 

withdrawn for the removal of the associated CRD, 

are disarmed.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.5.3 Verify a control rod withdrawal block is inserted. [ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Single CRD Removal - Refueling

3.10.5

General Electric BWR/6 STS 3.10.5-3 Rev. 4.0

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 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Multiple Control Rod Withdrawal - Refueling

3.10.6

General Electric BWR/6 STS 3.10.6-1 Rev. 4.0

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 

above requirements not 

met.

A.1 Suspend withdrawal of 

control rods and removal of 

associated CRDs.

AND

A.2 Suspend loading fuel 

assemblies.

AND

A.3.1 Initiate action to fully insert 

all control rods in core cells 

containing one or more fuel 

assemblies.

 OR

Immediately

Immediately

Immediately
Multiple Control Rod Withdrawal - Refueling

3.10.6

General Electric BWR/6 STS 3.10.6-2 Rev. 4.0

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.3.2 Initiate action to satisfy the 

requirements of this LCO.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.6.1 Verify the four fuel assemblies are removed from 

core cells associated with each control rod or CRD 

removed.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.6.2 Verify all other control rods in core cells containing 

one or more fuel assemblies are fully inserted.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Multiple Control Rod Withdrawal - Refueling

3.10.6

General Electric BWR/6 STS 3.10.6-3 Rev. 4.0

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 

compliance with an approved [spiral] reload 

sequence.

[ 24 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

Control Rod Testing - Operating

3.10.7

General Electric BWR/6 STS 3.10.7-1 Rev. 4.0

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 

LCO not met.

A.1 Suspend performance of 

the test and exception to 

LCO 3.1.6.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.7.1 Verify movement of control rods is in compliance 

with the approved control rod sequence for the 

specified test by a second licensed operator or other 

qualified member of the technical staff.

During control rod 

movement

SDM Test - Refueling

3.10.8

General Electric BWR/6 STS 3.10.8-1 Rev. 4.0

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.
SDM Test - Refueling

3.10.8

General Electric BWR/6 STS 3.10.8-2 Rev. 4.0

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. ------------NOTE------------

Separate Condition entry 

is allowed for each 

control rod.

---------------------------------

One or more control 

rods not coupled to its 

associated CRD.

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

Inoperable control rods may be 

bypassed in accordance with 

SR 3.3.2.1.9, if required, to allow 

insertion of inoperable control rod 

and continued operation.

------------------------------------------------

A.1 Fully insert inoperable 

control rod.

AND

A.2 Disarm the associated 

CRD.

3 hours

4 hours

B. One or more of the 

above requirements not 

met, for reasons other 

than Condition A.

B.1 Place the reactor mode 

switch in the shutdown or 

refuel position.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.8.1 Perform the MODE 2 applicable SRs for 

LCO 3.3.1.1, Functions 2.a and 2.d of 

Table 3.3.1.1-1.

According to the 

applicable SRs

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 

LCO 3.3.2.1, Function 1.b of Table 3.3.2.1-1.

According to the 

applicable SRs
SDM Test - Refueling

3.10.8

General Electric BWR/6 STS 3.10.8-3 Rev. 4.0

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 

with the approved control rod sequence for the SDM 

test by a second licensed operator or other qualified 

member of the technical staff.

During control

rod movement

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 

progress.

[ 12 hours

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]

SR 3.10.8.5 Verify each withdrawn control rod does not go to the 

withdrawn overtravel position.

Each time the 

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
SDM Test - Refueling

3.10.8

General Electric BWR/6 STS 3.10.8-4 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.8.6 Verify CRD charging water header pressure 

 1520 psig.

[ 7 days

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Recirculation Loops - Testing

3.10.9

General Electric BWR/6 STS 3.10.9-1 Rev. 4.0

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 hours 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 

LCO 3.4.1 not met for 

> 24 hours.

A.1 Insert all insertable control 

rods.

[1] hour

B. Requirements of the 

LCO not met for reasons

other than Condition A.

B.1 Place the reactor mode 

switch in the shutdown 

position.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.9.1 Verify LCO 3.4.1 requirements suspended for 

 24 hours.

[ 1 hour

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Recirculation Loops - Testing

3.10.9

General Electric BWR/6 STS 3.10.9-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.9.2 Verify THERMAL POWER is  [5]% RTP during 

PHYSICS TESTS.

[ 1 hour

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Training Startups

3.10.10

General Electric BWR/6 STS 3.10.10-1 Rev. 4.0

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 < 200F.

APPLICABILITY: MODE 2 with one LPCI subsystem suction valve closed.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the 

above requirements not 

met.

A.1 Place the reactor mode 

switch in the shutdown 

position.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.10.1 Verify all OPERABLE IRM channels are  [25/40] 

divisions of full scale on Range 7.

[ 1 hour

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Training Startups

3.10.10

General Electric BWR/6 STS 3.10.10-2 Rev. 4.0

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.10.2 Verify average reactor coolant temperature is 

< 200F.

[ 1 hour

OR

In accordance 

with the

Surveillance 

Frequency

Control Program ]
Design Features

4.0

General Electric BWR/6 STS 4.0-1 Rev. 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. ]
Design Features

4.0

General Electric BWR/6 STS 4.0-2 Rev. 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.
Responsibility

5.1

General Electric BWR/6 STS 5.1-1 Rev. 4.0

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.

Organization

5.2

General Electric BWR/6 STS 5.2-1 Rev. 4.0

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 nonlicensed operators for the two units.

------------------------------------------------------------------------------------------------------------
Organization

5.2

General Electric BWR/6 STS 5.2-2 Rev. 4.0

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 hours 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 hours, 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.
Unit Staff Qualifications

5.3

General Electric BWR/6 STS 5.3-1 Rev. 4.0

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).

Procedures

5.4

General Electric BWR/6 STS 5.4-1 Rev. 4.0

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.

Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-1 Rev. 4.0

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.
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-2 Rev. 4.0

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

--------------------------------------REVIEWER’S 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
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-3 Rev. 4.0

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,
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-4 Rev. 4.0

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 prestressed 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. ]
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-5 Rev. 4.0

5.5 Programs and Manuals

5.5.7 Inservice Testing Program

This program provides controls for inservice testing of ASME Code Class 1, 2, 

and 3 components. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and 

Maintenance of Nuclear Power Plants (ASME OM Code) and applicable 

Addenda as follows:

ASME OM Code and applicable 

Addenda terminology for 

inservice testing activities

Required Frequencies for 

performing inservice testing 

activities

Weekly At least once per 7 days

Monthly At least once per 31 days

Quarterly or every 3 months At least once per 92 days

Semiannually or every 6 months At least once per 184 days

Every 9 months At least once per 276 days

Yearly or annually At least once per 366 days

Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required 

Frequencies and to other normal and accelerated Frequencies specified as 

2 years or less in the Inservice Testing Program for performing inservice 

testing activities,

c. The provisions of SR 3.0.3 are applicable to inservice testing activities, and

d. Nothing in the ASME OM Code shall be construed to supersede the 

requirements of any TS.

5.5.8 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%]:
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-6 Rev. 4.0

5.5 Programs and Manuals

5.5.8 Ventilation Filter Testing Program (continued)

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 30C (86F) 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 30C (86F) and a relative humidity (RH) of 95% 

(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 30C (86F) 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.
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-7 Rev. 4.0

5.5 Programs and Manuals

5.5.8 Ventilation Filter Testing Program (continued)

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.

5.5.9 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:
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-8 Rev. 4.0

5.5 Programs and Manuals

5.5.9 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

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.

5.5.10 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:

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
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-9 Rev. 4.0

5.5 Programs and Manuals

5.5.10 Diesel Fuel Oil Testing Program (continued)

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.

5.5.11 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 5.5.11b above shall be reviewed 

and approved by the NRC prior to implementation. Changes to the Bases 

implemented without prior NRC approval shall be provided to the NRC on a 

frequency consistent with 10 CFR 50.71(e).

5.5.12 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,
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-10 Rev. 4.0

5.5 Programs and Manuals

5.5.12 Safety Function Determination Program (continued)

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.

5.5.13 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.
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-11 Rev. 4.0

5.5 Programs and Manuals

5.5.13 Primary Containment Leakage Rate Testing Program (continued)

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, "PerformanceBased 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:
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-12 Rev. 4.0

5.5 Programs and Manuals

5.5.13 Primary Containment Leakage Rate Testing Program (continued)

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, 

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. . . . ]
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-13 Rev. 4.0

5.5 Programs and Manuals

5.5.13 Primary Containment Leakage Rate Testing Program (continued)

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.

f. Nothing in these Technical Specifications shall be construed to modify the 

testing Frequencies required by 10 CFR 50, Appendix J.

5.5.14 Battery Monitoring and Maintenance Program

--------------------------------------REVIEWER’S 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:
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-14 Rev. 4.0

5.5 Programs and Manuals

5.5.14 Battery Monitoring and Maintenance Program (continued)

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:

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.

5.5.15 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 
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-15 Rev. 4.0

5.5 Programs and Manuals

5.5.15 Control Room Envelope (CRE) Habitability Program (continued)

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]

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 
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-16 Rev. 4.0

5.5 Programs and Manuals

5.5.15 Control Room Envelope (CRE) Habitability Program (continued)

CRE pressure and assessing the CRE boundary as required by 

paragraphs c and d, respectively.

5.5.16 [ Setpoint Control Program

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;"

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 Core Isolation Cooling (RCIC) System 

Instrumentation;"

9. LCO 3.3.6.1, "Primary Containment Isolation Instrumentation;"

10. LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation;"

11. LCO 3.3.6.3, "Low-Low Set (LLS) Instrumentation;"

12. LCO 3.3.7.1, "[Main Control Room Environmental Control (MCREC)] 

System Instrumentation;"

13. LCO 3.3.8.1, "Loss of Power (LOP) Instrumentation;"

14. 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 AsLeft 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 
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-17 Rev. 4.0

5.5 Programs and Manuals

5.5.16 Setpoint Control Program (continued)

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. 

d. ---------------------------------- REVIEWER’S 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. 

----------------------------------------------------------------------------------------------------
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-18 Rev. 4.0

5.5 Programs and Manuals

5.5.16 Setpoint Control Program (continued)

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 

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]. ]

5.5.17 [ 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.
Programs and Manuals

5.5

General Electric BWR/6 STS 5.5-19 Rev. 4.0

5.5 Programs and Manuals

5.5.17 Surveillance Frequency Control Program (continued)

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. ]

Reporting Requirements

5.6

General Electric BWR/6 STS 5.6-1 Rev. 4.0

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.
Reporting Requirements

5.6

General Electric BWR/6 STS 5.6-2 Rev. 4.0

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. ]

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:

--------------------------------REVIEWER’S 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. ]
Reporting Requirements

5.6

General Electric BWR/6 STS 5.6-3 Rev. 4.0

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:

--------------------------------REVIEWER’S 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. 

----------------------------------------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 NRCapproved 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.
Reporting Requirements

5.6

General Electric BWR/6 STS 5.6-4 Rev. 4.0

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. ]

----------------------------------------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.

------------------------------------------------------------------------------------------------------------
High Radiation Area

5.7

General Electric BWR/6 STS 5.7-1 Rev. 4.0

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
High Radiation Area

5.7

General Electric BWR/6 STS 5.7-2 Rev. 4.0

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.
High Radiation Area

5.7

General Electric BWR/6 STS 5.7-3 Rev. 4.0

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.
High Radiation Area

5.7

General Electric BWR/6 STS 5.7-4 Rev. 4.0

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.