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| number = ML16259A059
| number = ML16259A059
| issue date = 10/19/2016
| issue date = 10/19/2016
| title = Lasalle County, Unit 1, License Appendix a and B
| title = License Appendix a and B
| author name = Mitchell J S
| author name = Mitchell J
| author affiliation = NRC/NRR/DLR/RPB1
| author affiliation = NRC/NRR/DLR/RPB1
| addressee name =  
| addressee name =  
Line 9: Line 9:
| docket = 05000373, 05000374
| docket = 05000373, 05000374
| license number = NPF-011, NPF-018
| license number = NPF-011, NPF-018
| contact person = Mitchell J S
| contact person = Mitchell J
| document type = Technical Specifications
| document type = Technical Specifications
| page count = 389
| page count = 389
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=Text=
=Text=
{{#Wiki_filter:TABLE OF CONTENTS 1.0 USE AND APPLICATION 1.1 Definitions
{{#Wiki_filter:}}
..............................................
1.1-1 1.2 Logical Connectors
.......................................
1.2-1 1.3 Completion Times .........................................
1.3-1 1.4 Frequency
................................................
1.4-1 2.0 SAFETY LIMITS (SLs)2.1 SLs ...... ...........................................
2.0-1 2.2 SL Violations
............................................
2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY
........ 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY
.................
3.0-4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) ....................................
3.1.1-1 3.1.2 Reactivity Anomalies
.....................................
3.1.2-1 3.1.3 Control Rod OPERABILITY
..................................
3.1.3-1 3.1.4 Control Rod Scram Times ..................................
3.1.4-1 3.1.5 Control Rod Scram Accumulators
...........................
3.1.5-1 3.1.6 Rod Pattern Control ......................................
3.1.6-1 3.1.7 Standby Liquid Control (SLC) System ......................
3.1.7-1 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ....... 3.1.8-1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) ...... 3.2.1-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) ......................
3.2.2-1 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) ......................
3.2.3-1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation
..........
3.3.1.1-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation
...............
3.3.1.2-1 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation..
.3.3.1.3-1 3.3.2.1 Control Rod Block Instrumentation
........................
3.3.2.1-1 3.3.2.2 Feedwater System and Main Turbine High Water Level Trip Instrumentation
....................
.........3.3.2.2-1 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation
...........
3.3.3.1-1 3.3.3.2 Remote Shutdown Monitoring System ........................
3.3.3.2-1 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)Instrumentation
........................................
3.3.4.1-1 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT)
Instrumentation
...................
3.3.4.2-1 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation
..... 3.3.5.1-1 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation
........3.3.5.2-1 3.3.6.1 Primary Containment Isolation Instrumentation............
3.3.6.1-1 3.3.6.2 Secondary Containment Isolation Instrumentation
..........
3.3.6.2-1 3.3.7.1 Control Room Area Filtration (CRAF) System Instrumentation
........................................
3.3.7.1-1 (continued)
LaSalle 1 and 2 i Amendment No. 177/163 TABLE OF CONTENTS (continued) 3.7 3. 7. 1 3.7.2 3.7.3 3.7.4 3.7.5 3.7.6 3.7.7 3.7.8 3.8 3.8.1 3.8.2 3.8.3 3.8.4 3.8.5 3.8.6 3.8.7 3.8.8 3.9 3.9.1 3.9.2 3.9.3 3.9.4 3.9.5 3.9.6 3.9.7 3.9.8 3.9.9 3.10 3. 10. 1 3.10.2 3.10.3 3.10.4 3.10.5 3.10.6 3.10.7 3.10.8 PLANT SYSTEMS Residual Heat Removal Service Water CRHRSWJ System ....... 3.7.1-1 Diesel Generator Cooling Water CDGCWJ System .............
3.7.2-1 Ultimate Heat Sink (UHSJ .................................
3.7.3-1 Control Room Area Filtration CCRAF) System ...............
3.7.4-1 Control Room Area Ventilation Air Conditioning CACJ System ...............................
3.7.5-1 Main Condenser Offgas ....................................
3.7.6-1 Main Turbine Bypass System ...............................
3.7.7-1 Spent Fuel Storage Pool Water Level ......................
3.7.8-1 ELECTRICAL POWER SYSTEMS AC Sources-Operating
.....................................
3.8.1-1 AC Sources-Shutdown
......................................
3.8.2-1 Diesel Fuel Oil and Starting Air .........................
3.8.3-1 DC Sources-Operating
.....................................
3.8.4-1 DC Sources-Shutdown
......................................
3.8.5-1 Battery Parameters
.......................................
3.8.6-1 Distribution Systems-Operating
...........................
3.8.7-1 Distribution Systems-Shutdown
............................
3.8.8-1 REFUELING OPERATIONS Refueling Equipment Interlocks
...........................
3.9.1-1 Refuel Position One-Rod-Out Interlock
....................
3.9.2-1 Control Rod Position .....................................
3.9.3-1 Control Rod Position Indication
..........................
3.9.4-1 Control Rod OPERABILITY-Refueling
........................
3.9.5-1 Reactor Pressure Vessel (RPVJ Water Level-Irradiated Fuel ...................................................
3.9.6-1 Reactor Pressure Vessel CRPVJ Water Level-New Fuel or Control Rods ...................................
3.9.7-1 Residual Heat Removal CRHRJ-High Water Level .............
3.9.8-1 Residual Heat Removal CRHRJ-Low Water Level ..............
3.9.9-1 SPECIAL OPERATIONS Reactor Mode Switch Interlock Testing ....................
3.10.1-1 Single Control Rod Withdrawal-Hot Shutdown ...............
3.10.2-1 Single Control Rod Withdrawal-Cold Shutdown ..............
3.10.3-1 Single Control Rod Drive (CRD) Removal-Refueling
......................................
3.10.4-1 Multiple Control Rod Withdrawal-Refueling
................
3.10.5-1 Control Rod Testing-Operating
............................
3.10.6-1 SHUTDOWN MARGIN (SDMJ Test-Refueling
.....................
3.10.7-1 Inservice Leak and Hydrostatic Testing Operation
.........
3.10.8-1 (continued)
LaSalle 1 and 2 i i i Amendment No .219 I 205 TABLE OF CONTENTS .(continued) 3.7 3.7.1 3.7.2 3.7.3 3.7.4 3.7.5 3..7.6 3.7.7 3.7.8 3.8 3.8.1 3.8.2 3.8.3 3.8.4 3.8.5 3.8,6 .3.8.7 3.8.8 3.9 3.9.1 3.9.2 3.9.3 3.9.4 3.9.5 3.9.6 3.9.7 3.9.8 3.9.9 3.10 3.10.1 3.10.2 3.10.3 3.10.4 3.10.5 3.10.6 3.10.7 PLANT SYSTEMS Residual Heat Removal Service Water (RHRSW) System ....... 3.7.1-1 Diesel Generator Cooling Water (DGCW) System .............
3.7.2-1 Ultimate Heat Sink (UHS) .................................
3.7.3-1 Control Room Area Filtration (CRAF) System ...............
3.7.4-1 Control Room Area Ventilation Air Conditioning (AC) System ...............................
3.7.5-1 Main Condenser Offgas ....................................
3.7.6-1 Main Turbine Bypass System ...............................
3.7.7-1 Spent Fuel Storage Pool Water Level ......................
3.7.8-1 ELECTRICAL POWER SYSTEMS AC Sources-Operating
.....................................
3.8.1-1 AC Sources-Shutdown
.......................................
3.8.2-1 Diesel Fuel Oil and Starting Air .........................
3.8.3-1 DC Sources-Operating
.....................................
3.8.4-1 DC Sources-Shutdown
....................................
3.8.5-1_B e Distribution Systems-Operating
...........................
3.8.7-1 Distribution Systems-Shutdown
............................
3.8.8-1 REFUELING OPERATIONS Refueling Equipment Interlocks
...........................
3.9.1-1 Refuel Position One-Rod-Out Interlock
....................
3.9.2-1 Control Rod Position .....................................
3.9.3-1 Control Rod Position Indication
..........................
3.9.4-1 Control Rod OPERABILITY-Refueling
........................
3.9.5-1 Reactor Pressure Vessel (RPV) Water Level-Irradiated F u e l ........................ ...........................3 .9 .6 -1 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods ...............
....... ...........
3.9.7-1 Residual Heat Removal (RHR)-High Water Level .............
3.9.8-1 Residual Heat Removal (RHR)-Low Water Level .............
3.9.9-1 SPECIAL OPERATIONS Reactor, Mode Switch Interlock Testing ...................
: 3. .10.1-1 Single Control Rod Withdrawal-Hot Shutdown ...............
3.10.2-1 Single Control Rod Withdrawal-Cold Shutdown ..............
3.10.3-1 Single Control Rod Drive (CRD)Removal-Refueling
......................................
3.10.4-1 Multiple Control Rod Withdrawal-Refueling
................
3.10.5-1 Control Rod Testing-Operating
............................
3.10.6-1 SHUTDOWN MARGIN (SDM) Test-Refueling
.....................
3.10.7-1 (continued)
LaSalle I and 2 ii i Amendment No.1 7 9/165 TABLE OF CONTENTS (continued) 4.0 DESIGN FEATURES 4.1 Site Location .... .................4.0-1 4.2 Reactor Core .... .................4.0-1 4.3 Fuel Storage .... .................4.0-2 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility
....................5.1-1 5.2 Organization
.....................5.2-1 5.3 Unit Staff Oualifications
...............5.3-1 5.4 Procedures..
.... 5.4-1 5.5 Programs and Manuals .................5.5-1 5.6 Reporting Requirements
................5.6-1 5.7 High Radiation Area ..................5.7-1 LaSalle 1 and 2 1 V Amendment No. 147/133 Definitions 1.1 1.0 USE AND APPLICATION
 
===1.1 Definitions===
--- ----------------------------
NOTE-------------------------------------
The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.Term ACTIONS Definition 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 HEAT GENERATION RATE (APLHGR)CHANNEL CALIBRATION CHANNEL CHECK The APLHGR shall be applicable to a specific planar height and is equal to the sum of the LHGRs 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.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.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.(continued)
'LaSalle I and 2 1.1 -1 Amendment No. 147/133 Definitions 1 .1 1.1 Definitions (continued)
CHANNEL FUNCTIONAL TEST CORE ALTERATION 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.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 REPORT (COLR)DOSE EQUIVALENT I-131 The COLR is the unit specific document that provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.
DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (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 (continued)
La$alle I and 2 1.1 -2 Amendment No. 147/133 Definitions 1.1 1.1 Definitions DOSE EQUIVALENT I-131 (continued)
EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT)
SYSTEM RESPONSE TIME Power and Test Reactor Sites;" Table E-7 of Regulatory Guide 1.109, Rev. 1. NRC, 1977; or ICRP 30, Supplement to Part 1, pages 192-212, Table titled, "Committed Dose Equivalent in Target Organs or Tissues per Intake of Unit Activity." The ECCS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ECCS initiation 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 method for verification have been previously reviewed and approved by the NRC.The EOC-RPT SYSTEM RESPONSE TIME shall be that time interval from initial signal generation by the associated turbine 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.
In lieu of measurement, response time may be verified for selected components provided that the components and method for verification have been previously reviewed and approved by the NRC.(continued)
LaSalle 1 and 2 1.1-3 Amendment No. 147/133 Definitions 1.1 1.1 Definitions (continued)
ISOLATION SYSTEM RESPONSE TIME The ISOLATION SYSTEM RESPONSE TIME shall be that 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.
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 method 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 d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.(continued)
LaSalle I and 2 1.1-4 Amendment No. 147/133 Definitions 1.1 1.1 Definitions (continued)
LINEAR HEAT GENERATION RATE (LHGR) LOGIC SYSTEM FUNCTIONAL TEST MINIMUM CRITICAL POWER RATIO (MCPR) MODE OPERABLE-OPERABILITY RATED THERMAL POWER (RTP) The LHGR shall be the heat generation rate per unit length of fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length. A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all 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. The MCPR shall be the smallest critical power ratio (CPR) that 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. A MODE shall correspond to anyone 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. 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).
RTP shall be a total reactor core heat trans r rate to the reactor coolant of 3546 MWt. (continued)
LaSalle 1 and 2 1. 1-5 Amendment No.198/185 Definitions 1.1 1.1 Definitions (continued)
REACTOR PROTECTION SYSTEM CRPS) RESPONSE TIME SHUTDOWN MARGIN (SDM) STAGGERED TEST BASIS THERMAL POWER LaSalle 1 and 2 The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at 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 method for verification have been previously reviewed and approved by the NRC. SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical throughout the operating cycle assuming that: a. The reactor is xenon free; b. The moderator temperature 68°F, corresponding to the most reactive state; and c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.
With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM. 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 shall be the total reactor core heat transfer rate to the reactor coolant. (continued)
: 1. 1-6 Arencirent 1\bs. 211 /197 Definitions 1.1 1.1 Definitions (continued)
TURBINE BYPASS SYSTEM RESPONSE TIME The TURBINE BYPASS SYSTEM RESPONSE TIME shall be that time interval from when the turbine bypass control unit generates a turbine bypass valve flow signal until the turbine bypass valves travel to their required positions.
The response time may be measured by means of any series of sequential.
overlapping, or total steps so that the entire response time is measured.LaSalle I and 2 1. 1-7 Amendment No. 147/133 Definitions 1.1 Table 1.1-1 (page 1 of 1)MODES REACTOR MODE AVERAGE REACTOR MODE TITLE SWITCH POSITION COOLANT TEMPERATURE (0 F)1 Power Operation Run NA 2 Startup Refuel(a) or Startup/Hot NA Standby 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.
X) (b) One or more reactor vessel head closure bolts less than fully tensioned.
La~alle 1 and 2 1.1-8 Amendment No. 147/133 Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.
Logical connectors are used in Technical Specifications (TS)to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times.Surveillances, and Frequencies.
The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentions of the logical connectors.
When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.
EXAMPLES The following examples illustrate the use of logical connectors.(continued)
LaSalle 1 and 2 1.2-1 Amendment No. 147/133 Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)
EXAMPLE 1.2-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify ...AND A.2 Restore ...In this example, the logical connector AND is used to indicate that, when in Condition A, both Required Actions A.1 and A.2 must be completed.(continued)
LaSalle I and 2 1.2-2 Amendment No. 147/133 Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)
EXAMPLE 1.2-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip ...OR A.2.1 Verify ...AND A.2.2.1 Reduce ...OR A.2.2.2 Perform ...OR A.3 Align ...This example represents a more complicated use of logical connectors.
Required Actions A.1. A.2, and A.3 are alternative choices. only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement.
Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND.Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.
LaSalle 1 and 2 1.2-3 Amendment No. 147/133 Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.
If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.
Once a Condition has been entered, subsequent 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.(continued)
LaSalle 1 and 2 1 .3-1 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times DESCRIPTION However, when a subsequent division, subsystem, component.(continued) or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended.
To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:
: a. Must exist concurrent with the first inoperability; and b. Must remain inoperable or not within limits after the first inoperability is resolved.The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either: a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours; or b. The stated Completion Time as measured from discovery of the subsequent inoperability.
The above Completion Time extension does not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each division, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry.
These exceptions are stated in individual Specifications.
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
..." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.(continued)
LaSalle 1 and 2 1.3-2 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)
EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 12 hours Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours met.Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.The Required Actions of Condition B are to be in MODE 3 within 12 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.(continued)
LaSalle 1 and 2 1.3-3 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)
EXAMPLE 1.3-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable.
OPERABLE status.B. Required B.1 Be in MODE 3. 12 hours Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours met.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, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated.
When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump.The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.While in LCO 3.0.3. if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.(continued)
La~alle 1 and 2 1.3-4 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)
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.(continued)
LaSalle I and 2 1.3-5 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)
EXAMPLE 1.3-3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore 7 days Function X Function X subsystem subsystem to AND inoperable.
OPERABLE status.10 days from discovery of failure to meet the LCO B. One B.1 Restore 72 hours Function Y Function Y subsystem subsystem to AND inoperable.
OPERABLE status.10 days from discovery of failure to meet the LCO C. One C.1 Restore 72 hours Function X Function X subsystem subsystem to inoperable.
OPERABLE status.AND OR One C.2 Restore 72 hours Function Y Function Y subsystem subsystem to inoperable.
OPERABLE status.(continued)
LaSalle I and 2 1.3-6 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)
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).
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).The Completion Times of Conditions A and B are modified by a logical connector, with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO.The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO.This Completion Time allows for an exception to the normal"time zero" for beginning the Completion Time 'clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.(continued)
La~alle 1 and 2 1.3-7 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)
EXAMPLE 1.3-4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) 4 hours valves to OPERABLE inoperable.
status.B. Required B.1 Be in MODE 3. 12 hours Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours met.A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis.Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable.
The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 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.(continued)
LaSalle 1 and 2 1.3-8 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)
EXAMPLE 1.3-5 ACTIONS----------------------------
NOTE ----------------------------
Separate Condition entry is allowed for each inoperable valve...- ----.--.-.-.---.-------------------------...-CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours valves OPERABLE status.inoperable.
B. Required B.1 Be in MODE 3. 12 hours Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours met.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.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.(continued)
LaSalle I and 2 1.3-9 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)
If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve.If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status. Condition B is exited for that valve.Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per inoperable.
SR 3.x.x.x. 8 hours OR A.2 Reduce THERMAL 8 hours POWER to< 50% RTP.B. Required B.1 Be in MODE 3. 12 hours Action and associated Completion Time not met.(continued)
LaSalle 1 and 2 1.3 -10 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)
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 begins when Condition A is entered and the initial performance of Required Action A.1 must be completed 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.(continued)
LaSalle 1 and 2 1.3- 11 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)
EXAMPLE 1.3-7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour subsystem subsystem inoperable.
isolated.
AND Once per 8 hours thereafter AND A.2 Restore subsystem 72 hours to OPERABLE status.B. Required B.1 Be in MODE 3. 12 hours Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours met.Required Action A.1 has two Completion Completion Time begins at the time the and each 'Once per 8 hours thereafter" performance of Required Action A.1.Times. The 1 hour Condition is entered interval begins upon 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 (continued)
LaSalle 1 and 2 1.3-12 Amendment No. 147/133 Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued) 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 COMPLETION TIME Required Action should be pursued without delay and in a controlled manner.--LaSalle 1 and 2 1.3-13 Amendment No. 147/133 Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.
DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Condition for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.The "specified Frequency' is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability.
The "specified Frequency' consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements.
Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated' conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Example 1.4-4 discusses these special situations.
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 specified 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.
SR 3.0.4 restrictions would not apply if both the following conditions are satisfied: (continued)
LaSalle 1 and 2 1 .4 -1 Amendment No. 147/133
-Frequency 1.4 1.4 Frequency DESCRIPTION
.a. The Surveillance is not required to be performed; and (continued)
: b. The Surveillance is not required to be met or, even if required to be met, is not known to be failed.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. The examples do not reflect the potential application of LCO 3.0.4.b.EXAMPLE 1.4-1 I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 112 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.
If the interval as specified the unit is not in a MODE or the Applicability of the LCO by SR 3.0.2 is exceeded while other specified condition in for which performance of the SR (continued)
LaSalle I and 2 1.4-2 Amendment ND. 171/157.
Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 (continued) is required, the Surveillance must Frequency requirements of. SR 3.0.2 MODE or other specified condition.
result in a violation of SR 3.0.4.be performed within the prior to entry into the Failure to do so would 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 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.(continued)
LaSalle I and 2 1.4-3 Amendment No. 147/133 Frequency 1.4 1.4 Frequency EXAMPLES EX AMPLE 1.4- (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY . ----. -----. ---
NOT E-. --.. ------... -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 Derformance 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 LCD. 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. (continued)
LaSalle 1 and 2 1. 4-4 Amendment No. 193/180 
---Frequency 1.4 1.4 Frequency EXAMPLES (continued)
EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY------------------
NOTE------------------
Only required to be met in MODE 1.Verify leakage rates are within limits. 24 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).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..LaSalle I and 2 1.4-5 Amendment No. 147/133 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.l Reactor Core SLs SLs 2.0 2.1.1.l With the reactor steam dome pressure<
700 psia or core flow< 10% rated core flow: THERMAL POWER shall bes 25% RTP. 2.1.1.2 With the reactor steam dome pressure 2 700 psia and core flow 2 10% rated core flow: For Unit 1, MCPR shall be 2 1.13 for two recirculation loop operation or 2 1.15 for single recirculation loop operation.
For Unit 2, MCPR shall 1.14 for two recirculation loop operation 1.17 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 bes 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. LaSalle 1 and 2 2.0-1 Amendment Nos. 220/206 LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (MCO) 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 and LCO 3.0.7.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;(continued)
LaSalle I and 2 3.0-1 Amendment No171/ 157 40 LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 (continued)
: 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.
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 systeh 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.LaSalle I and 2 3.0-2 Amendment No-1 7 t/1 5 7 LCO Applicability 3.0 3.0 LCO APPLICABILITY 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 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 LCOs, including associated ACTIONS, shall apply to each unit individually, unless otherwise indicated.
Whenever the LCO refers to a system or component that is shared by both units, the ACTIONS will apply to both units simultaneously.
LaSalle I and 2 3.0-3 Amendment No.171/157 SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3.Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.For Frequencies specified as "once," the above interval extension does not apply.If a Completion Time requires periodic performance on a"once per ..." basis, the above Frequency extension applies to each performance after the initial performance.
Exceptions to this Specification are stated in the individual Specifications.
SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to.declare the LCO not met may be delayed, from the time of discovery, up to 24 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.(continued)
LaSalle 1 and 2 3.0-4 Amendment No. 153 APR 0 8 2002 SR Applicability 3.0 3.0 SR APPLICABILITY SR 3.0.3 When the Surveillance is performed within the delay period (continued) 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.This provision shall not prevent entry Into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.SR 3.0.5 SRs shall apply to each unit individually, unless otherwise indicated.
LaSalle 1 and 2 3.0-5 Amendment No. /171/157 SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)LCO 3.1.1 SDM shall be: a. > 0.38% Ak/k. with the highest worth control rod analytically determined; or b. > 0.28% Ak/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 A.1 Restore SDM to within 6 hours in MODE I or 2. limits.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not met.C. SDM not within limits C.1 Initiate action to Immediately in MODE 3. fully insert all insertable control rods.D. SDM not within limits D.1 Initiate action to Immediately in MODE 4. fully insert all insertable control rods.AND (continued)
LaSalle I and 2 3.1 .1-1 Amendment No. 147/133 SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued)
D.2 Initiate action to 1 hour restore secondary containment to OPERABLE status.AND D.3 Initiate action to 1 hour restore one standby gas treatment (SGT)subsystem to OPERABLE status.AND D.4 Initiate action to 1 hour restore isolation capability in each required secondary containment penetration flow path not isolated.E. SDM not within limits E.1 Suspend CORE Immediately in MODE 5. ALTERATIONS except for control rod insertion and fuel assembly removal.AND (continued)
LaSalle 1 and 2 3.1.1- 2 Amendment No. 147/133 SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued)
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.Immediately 1 hour 1 hour 1 hour IAND 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.LaSalle I and 2 3.1.1-3 Amendment No. 147/133 SDM 3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4.SR 3.1.1.1 Verify SOM is: a. 2 0.38% Ak/k with the highest worth control rod analytically determined; or b. > 0.28% Ak/k with the highest worth control rod determined by test.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 LaSalle 1 and 2 3.1.1-4 Amendment No. 147/133 Reactivity Anomalies 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Reactivity Anomalies LCO 3.1.2 APPLICABILITY:
The reactivity difference between the monitored core keff and the predicted core keff shall be within +/- 1% Ak/k.MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity A.1 Restore core 72 hours difference not within reactivity difference limit. to within limit.B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met.LaSalle 1 and 2 3.1.2-1 Amendment No. 147/133
-Reactivity Anomalies 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify core reactivity difference between the monitored core keff and the predicted core keif is within i 1X Ak/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 LaSalle 1 and 2 3.1.2-2 Amendment No. 147/133 Control Rod OPERABILITY 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Control Rod OPERABILITY LCO 3.1.3 APPLICABILITY:
Each control rod shall be OPERABLE.MODES 1 and 2.ACTIONS---------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each control rod.CONDITION REQUIRED ACTION COMPLETION TIME A. One withdrawn control ------------
NOTE-------------
rod stuck. Rod Worth Minimizer (RWM) may be bypassed as allowed by LCO 3.3.2.1, "Control Rod Block Instrumentation," if required to allow continued operation.
A.1 Verify stuck control Immediately rod separation criteria are met.AND A.2 Disarm the associated 2 hours control rod drive (CRD).AND (continued)
LaSalle 1 and 2 3.1.3-1 Amendment No. 147/133 Control Rod OPERABILITY 3.1. 3 ACTIONS A. B. C. CONDITION (continued)
Two or more withdrawn control rods stuck. One or more control rods inoperable for reasons other than Condition A or B. A.3 A.4 B.1 C.1 REQUIRED ACTION Perform SR 3.1.3.3 for each withdrawn OPERABLE control rod. Perform SR 3.1.1.1. Be in MODE 3. --------NOTE------RWM may be bypassed as a 11 owe d by LCO 3.3.2.1, if required, to allow insertion of inoperable control rod and continued operation.
Fully insert inoperable control rod. COMPLETION TIME 24 hours from discovery of Condition A concurrent with THERMAL POWER greater than the low power setpoint (LPSP) of the RWM 72 hours 12 hours 3 hours C.2 Disarm the CRD. associated 4 hours (continued)
LaSalle 1 and 2 3.1.3-2 Amendment No. 193/180 Control Rod OPERABILITY 3.1.3 ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME-. ---------NOTE---------
D.1 Restore compliance 4 hours Not applicable when with analyzed rod THERMAL POWER position sequence.> lot RTP.-- OR Two or more inoperable D.2 Restore control rod 4 hours control rods not in to OPERABLE status.compliance with analyzed rod position sequence and not separated by two or more OPERABLE control rods.E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A.C. or D not met.OR Nine or more control rods inoperable.
LaSalle I and 2 3.1.3 -3 Amendment No. 147/133 Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. In accordance with the Surveillance Frequency Control Program SR 3.1.3.2 DELETED SR 3.1.3.3 Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM. Insert each withdrawn control rod at least one notch. In accordance with the Surveillance Frequency Control Program SR 3.1.3.4 Veri fy each control rod scram time from fully withdrawn to notch position 05 is 7 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 (continued)
LaSalle 1 and 2 3.1.3-4 Amendment No .200 / 187 Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY I.SR 3.1.3.5 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'LaSalle I and 2 3.1.3-5 Amendment No. 147/133 Control Rod Scram Times 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than 12 OPERABLE control rods shall be "slow." in accordance with Table 3.1.4-1; and b. No more than 2 OPERABLE control rods that are "slow" shall occupy adjacent locations.
APPLICABILITY:
MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Be in MODE 3. 12 hours LCO not met.SURVEILLANCE REQUIREMENTS
-------------------------
NOTE------------------------------------
During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.
SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is Prior to within the limits of Table 3.1.4-1 with exceeding reactor steam dome pressure > 800 psig. 40% RTP after each reactor shutdown > 120 days (continued)
LaSalle I and 2 3.1.4-1 Amendment No. 147/133 3.1.4 Control Rod Scram Times SURVEILLANCE REQUIREMENTS 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 800 psig. 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 OP E RAB LE a fte r work on control rod or CRD tern 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 800 psig. Prior to exceeding 40% RTP after fuel movement withi n the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that coul d affect scram time LaSalle 1 and 2 3.1.4 2 Amendment No. 200 / 187 Control Rod Scram Times 3.1.4 Table 3.1.4-1 Control Rod Scram Times-------------------------------------
NOTES------------------------------------
: 1. OPERABLE control rods with scram times not within the limits of this Table are considered
'slow." 2. Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod OPERABILITY," for control rods with scram times > 7 seconds to notch position 05. These control rods are inoperable, in accordance with SR 3.1.3.4, and are not considered "slow."______________________________________________________________________________
SCRAM TIMES(a)(b)(seconds) when reactor steam dome NOTCH POSITION pressure > 800 psig 45 0.52 39 0.80 25 1.77 05 3.20 (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 < 800 psig are within established limits.LaSalle I and 2 3.1.4 -3 Amendment No. 147/133
-.Control Rod Scram Accumulators 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCO 3.1.5 APPLICABILITY:
Each control rod scram accumulator shall be OPERABLE.MODES 1 and 2.ACTIONS----------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each control rod scram accumulator.
--- -------------------------------------CONDITION REQUIRED ACTION COMPLETION TIME A. One control rod scram A.1 --------NOTE--------
accumulator inoperable Only applicable if with reactor steam the associated dome pressure control rod scram> 900 psig. time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.
Declare the 8 hours associated control rod scram time.slow., OR A.2 Declare the 8 hours associated control rod inoperable.(continued)
LaSalle 1 and 2 3.1.5-1 Amendment No. 147/133 Control Rod Scram Accumulators 3.1.5 ACTIONS CONDITION I REOUIRED ACTION COMPLETION TIME B.1 B. Two or more control rod scram accumulators inoperable with reactor steam dome pressure 2 900 psig.Restore charging water header pressure to > 940 psig.AND 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.
20 minutes from discovery of Condition B concurrent with charging water header pressure< 940 psig 1 hour 1 hour C. One or more control C.1 Verify all control Immediately upon rod scram accumulators rods associated with discovery of inoperable with inoperable charging water reactor steam dome accumulators are header pressure pressure < 900 psig. fully inserted.
< 940 psig AND (continued)
LaSalle 1 and 2 3.1.5 -2 Amendment No. 147/133 Control Rod Scram Accumul ators 3.1. 5 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)
C.2 Declare the associated control rod inoperable.
1 hour D. Required Action B.1 or C.1 and associated Completion Time not met. D.1
---Not applicable if all inoperable control rod scram accumulators are associ ated with fully inserted control rods. Place the reactor mode switch in the shutdown position.
Immediately SURVEILLANCE SR 3.1.5.1 Verify each control rod scram accumulator pressure is 940 psig.
In accordance with the Surveillance Frequency Control Program LaSall eland 2 3.1.5-3 Amendment No.200 1187 Rod Pattern Control 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Rod Pattern Control LCO 3.1.6 APPLICABILITY:
OPERABLE control rods shall comply with the requirements of the analyzed rod position sequence.MODES 1 and 2 with THERMAL POWER < 10% RTP.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more OPERABLE A.1 --------NOTE---------
control rods not in Rod Worth Minimizer compliance with the (RWM) may be bypassed analyzed rod position as allowed by sequence.
LCO 3.3.2.1, 'Control Rod Block Instrumentation." Move associated 8 hours control rod(s) to correct position.OR A.2 Declare associated 8 hours control rod(s)inoperable.(continued)
LaSalle 1 and 2 3.1.6-1 Amendment No. 147/133 Rod Pattern Control 3.1. 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE control rods not in compliance with the analyzed rod position sequence.
B.1 B.2 --NOTE -----RWM may be bypassed as allowed by LCD 3.3.2. 1. Suspend withdrawal of control rods. Place the reactor mode switch in the shutdown position.
Immediately 1 hour SURVEILLANCE SR 3.1.6.1 V e r if y all 0P E RA BL E con t r 0 1 rod s com ply with the analyzed rod position sequence.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.1.6-2 Amendment No .200 / 187 SLC System 3.1. 7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) LCO 3.1. 7 Two SLC subsystems shall be APPLICABILITY:
MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SLC subsystem inoperable.
A.l Restore SLC subsystem to OPERABLE status. 7 days B. Two SLC subsystems inoperable.
B.1 Restore one SLC subsystem to OPERABLE status. 8 hours C. Required Action and associated Completion Ti me not met. C.1 C.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours SURVEILLANCE SURVEI SR Verify available volume of sodium pentaborate solution is within the limits of Figure 3.1.7 1.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.1.7 1 Amendment No .200 / 187 SLC System 3.1. 7 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.1.7.2 Verify temperature of sodium penta borate solution is within the limits of Figure 3.1.72. In accordance with the Surveillance Frequency Control Program SR 3.1.7.3 Verify temperature of pump suction piping up to the storage tank outlet valves is ;;:: 68&deg;F. In accordance with the Surveillance Frequency Control Program SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.1.7-2 Amendment No. 200 / 187 SLC System 3.1. 7 SURVEILLANCE REQUIREMENTS SR 3.1.7.5 SURVEILLANCE Verify the concentration of sodium penta borate in solution is within the limits of Figure 3.1.7 1. FREQUENCY In accordance with the Surveillance Frequency Contro 1 Program Once within 24 hours after water or sodium penta borate is added to solution SR SR 3.1.7.6 3.1.7.7 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.
Verify each pump develops a flow rate 41.2 gpm at a discharge pressure 1220 psig. Once within 24 hours after solution temperature is restored within the 1 i mits of Figure 3.1.7-2 In accordance with the Surveillance Frequency Control Program In accordance with the Inservice Testing Program (continued)
LaSalle 1 and 2 3.1.7-3 Amendment No. 200 / 187 SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SR 3.l.7.9 Verify all heat traced plplng between In accordance SURVEILLANCE FREQUENCY SR 3.l.7.8 Verify flow through one SLC subsystem from pump into reactor pressure vessel. In accordance with the Surveillance Frequency Control Program storage tank and storage tank outlet valves with the is unblocked.
Surveillance Frequency Control Program Once withi n 24 hours after piping temperature is restored within the 1 i mits of Figure 3.1.7 2 LaSalle 1 and 2 3.1.7 4 Amendment No. 200 I 187 5200 SLC System 3.1. 8 f-< t) .0%, Gal) U naccep tab Ie Operation (13.4%, 4587 Gal) (13.8%, 5150 Gal) (13.8%, 4587 Gal) 11 12 13 14 Concentration
(% by weight) Figure 3.1.7-1 (page 1 of Sodium Penta borate Solution Volume/Concentration LaSalle 1 and 2 3.1.7-5 Amendment NO.200 /187 SLC System 3.1. LL o (J) L :::l rtl L (J) E (J) f-5 30 35 Concentration
(% by Acceptable Operation 10 15 20 25 Unacceptable Operation Figure 3.1.7-2 (page 1 of Sodium Pentaborate Solution Temperature/Concentration LaSalle 1 and 3.1.7-6 Amendment NO'200 /187 SDV Vent and Drain Valves 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves LCO 3.1.8 APPLICABILITY:
Each SDV vent and drain valve shall be OPERABLE.MODES 1 and 2.ACTIONS----------------------------
NOTES------------------------------------
: 1. Separate Condition entry is allowed for each SDV vent and drain line.2. An isolated line may be unisolated under administrative control to allow draining and venting of the SDV.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SDV vent A.1 Isolate the 7 days or drain lines with associated line.one valve inoperable.
B. One or more SDV vent B.1 Isolate the 8 hours or drain lines with associated line.both valves inoperable.
C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time not met.LaSalle I and 2 3.1 .8-1 Amendment No. 147/133 SDV Vent and Drain Valves 3.1. 8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR -------------------
NOT E-------------------
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 In accordance open. with the Surveillance Frequency Control Program SR 3.1.8.2 Cycle each SDV vent and drain valve to the In accordance fully closed and fully open position. the Surveillance Frequency Control Program In accordance with the SR Verify each SDV vent and drain valve: a. Closes 30 seconds after receipt Surveillance of an actua 1 or s i mul ated scram Frequency signal; and Control Program Opens when the actual or simulated scram signal is reset. LaSalle 1 and 3.1.8-2 Amendment 200 / 187 APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) LCO 3.2.1 All APLHGRs shall be less specified in the COLR. than or equal to the limits APPLICABILITY:
THERMAL POWER 25% RTP. ACTIONS CONDITION REQUIRED ACTION I COMPLETION TIME A. Any APLHGR not within limits. B. Required Action and associated Completion Time not met. A.1 B.1 Restore APLHGR(s) to withi n 1 i mits. Reduce THERMAL POWER to < 25% RTP. 2 hours 4 hours SURVEILLANCE 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 In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.2.1-1 Amendment No .200 I 187 MCPR 3.2.2 3.2 POWER DISTRIBUTION 3.2.2 MINIMUM CRITICAL LIMITS POWER RATIO (MCPR) LCD 3.2.2 All MCPRs operating shall be greater limits specified than or equal in the COLR. to the MCPR APPLICABILITY:
THERMAL POWER 25% RTP. ACTIONS CONDITION REQU I RED ACTI ON COMPLETI ON TIME A. Any MCPR not within 1 imits. A.l Restore MCPR(s) to withi n 1 i mits. 2 hours B. Required Action and associated Completion Time not met. B.l Reduce THERMAL POWER to < 25% RTP. 4 hours SURVEILLANCE 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 In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.2.2 1 Amendment No. 200/ 187 MCPR 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours after each completion of SR 3.1.4.1 AND Once within 72 hours after each completion of SR 3.1.4.2 AND Once within 72 hours after each completion of SR 3.1.4.4 LaSall1e 1 and 2 3.2.2- 2 Amendment No. 147/133 LHGR 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) LCO 3.2.3 All LHGRs specified shall be 1 ess in the COLR. than or equal to the 1 imits APPLICABILITY:
THERMAL POWER 25% RTP. ACTIONS CONDITION REQUIRED ACT I ON COMPLETION TIME A. Any LHGR not withi n 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 SURVEI SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits specified in the COLR.
Once within 12 hour s after 2: 25% RTP In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.2.3-1 Amendment No. 200 / 187 RPS Instrumentation 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation LCO 3.3.1.1 APPLICABILITY:
The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.According to Table 3.3.1.1-1.
ACTIONS--- -------------------------------
NOTES------------------------------------
: 1. Separate Condition entry is allowed for each channel.2. When Functions 2.b and 2.c channels are inoperable due to the APRM indication not within limits, entry into associated Conditions and Required Actions may be delayed for up to 2 hours if the APRM is indicating a lower power value than the calculated power, and for up to 12 hours if the APRM is indicating a higher power value than the calculated power........- -------------. ..... -------.....- --.-.. ........-
---------------------............
...- --------. .. ..- ---. .CONDITION REOUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in 12 hours channels inoperable.
trip.OR A.2 Place associated trip 12 hours system in trip.B. One or more Functions B.1 Place channel in one 6 hours with one or more trip system in trip.required channels inoperable in both .OR trip systems.B.2 Place one trip system 6 hours in trip.(continued)
LaSalle 1 and 2 3.3.1 .1 -1 Amendment No. 147/133 RPS Instrumentation 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Restore RPS trip 1 hour with RPS trip capability.
capability not maintained.
D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A. Table 3.3.1.1-1 for B. or C not met. the channel.E. As required by E.1 Reduce THERMAL POWER 4 hours Required Action D.1 to < 25% RTP.and referenced in Table 3.3.1.1-1.
F. As required by F.1 Be in MODE 2. 6 hours Required Action D.1 and referenced in Table 3.3.1.1-1.
G. As required by G.1 Be in MODE 3. 12 hours Required Action 0.1 and referenced in Table 3.3.1.1-1.
H. As required by H.1 Initiate action to Immediately Required Action D.1 fully insert all and referenced in insertable control Table 3.3.1.1-1.
rods in core cells containing one or more fuel assemblies.
LaSalle 1 and 2 3.3.1.1-2 Amendment No. 147/133 Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function. 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. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.2 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 while operating at 25% RTP. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.3 Adjust the channel to conform calibrated flow signal. to a In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.3.1.1-3 Amendment No. 200/ 187 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.4
------------------NOTE Not required to be performed when entering MODE 2 from MODE 1 until 24 hours after entering MODE 2. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.6 Verify the source range monitor (SRM) and intermediate range monitor (IRM) channels overlap. Prior to fully withdrawing SRMs SR 3.3.1.1.7 Only required to be met during entry into MODE 2 from MODE 1. Verify the IRM and APRM channels overlap. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.8 Calibrate the local power range monitors.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.3.1.1-4 Amendment No. 200 / 187 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.10 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.11 1. Neutron detectors are excluded.
: 2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 24 hours after entering MODE 2. Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
LaSall eland 2 3.3.1.1-5 Amendment No. 2001 187 Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 3.3.1.1.13
------Neutron detectors are excluded. For Function 1.a, not required to be performed when entering MODE 2 from MODE 1 until 24 hours after entering MODE 2. Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.14 Verify the APRM Flow Biased Simulated In accordance Thermal Power-Upscale time constant is with the 7 seconds. Surveillance Frequency Control Program SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program In accordance Turbine Control Valve Fast Closure, Trip SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and with the Oil Pressure-Low Functions are not Surveillance bypassed when THERMAL POWER is 25% RTP. Frequency Control Program (contlnued)
LaSalle 1 and 3.3.1.1-6 Amendment No. 200/ 187 Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS 3.3.1.1.17
----NOTES Neutron detectors are excluded. For Function 9, the RPS RESPONSE TIME is measured from start of turbine control valve fast closure. Verify the RPS RESPONSE TIME is within limits.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.3.1.1 7 Amendment No. 200 I 187 RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3) Reactor Protection System Instrumentation APPLICA3LE REQUIRED CONDITIONS MODES OR OTHER CHMNELS REFERENCED SPECIFIED PER TRIP FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CDND IT IONS SYSTEM ACTION 0.1 REQUIREMENTS VALUE I. Intermediate Range Monitors a. Neutron Fl uxHi gh 2 b. Inop 2 2. Average Power Range Monitors a. Neutron Flux-High, Setdown 2 b. Flow 3iased Simulated Therma 1 Power-Upsca 1 e c. Fixed Neutron Flux-High 3 G SR SR SR SR SR SR H SR SR SR SR 3 G SR SR 3 H SR SR 2 G SR SR SR SR SR SR 2 SR SR SR SR SR SR SR SR 2 SR SR SR SR SR SR SR 3.3.1.1.1 3.3.1.1.4 3.3.1.1.6 3.3.1.1.7 3.3.1.1.13 3.3.1.1.15 3.3.1.1.1 3.3.1.1.5 3.3.1.1.13 3.3.1.1.15 3.3.1.1.4 3.3.1.1.15 3.3.1.1.5 3.3.1.1.15 3.3.1.1.1 3.3.1.1.4 3.3.1.1.7 3.3.1.1.8 3.3.1.1.11 3.3.1.1.15 3.3.1.1.1 3.3.1.1.2 3.3.1.1.3 3.3.1.1.8 3.3.1.1.9 3.3.1.1.11
(" 3.3.1.1.14 3.3.1.1.15 3.3.1.1.1 3.3.1.1.2 3.3.1.1.8 3.3.1.1.9 3.3.1.1.11 3.3.1.1.15 3.3.1.1.17
::: 1231125 divisions of full scale ::: 1231125 divisions of full scale NA NA s: 20% RTP s: 0.61 W+ 68.2% RTP and s: 115.5% RTPtrl) ::: 120% RTP (continued) (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.
Ib) If teas-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be eva1 ated to verify that it is functioning as required before returning the channel to service. Ic) The nstrument channel nt shall be reset to a value that is within the as left tolerance around the nominal trip setpoint ( ) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.
Setpoints more conservative than the NTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (field setting) to confirm channel performance.
The NTSP and the methodologies used to determine the as-found and the as-left tolerances are specified in the Technical Requirements Manual. (d) Allowable Value is 0.54 W+ 55.91 RTP and::: 112.31 RTP when reset for single loop operation per LCD 3.4.1, "Recirculation Loops Operating." LaSalle 1 and 2 3.3,1.1-8 Amendment No. 200 1 187 RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3) Reactor Protection System Instrumentation FUNCTION APPLICA3LE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANN E LS PER TRIP SYSTEM CONDITIONS REFERENCED FROM REQUIRED ACTION 0.1 SURVEI LLANCE REQU I REMENTS ALLOWAB L E VALUE 2. Average Power Range f1onitors (continued)
: d. lnop 1,2 2 G SR SR SR 3.3.l.l.8 3.3.l.1.9 3.3.l.1.15 NA 3. Reactor Vessel Pressure-High Steam Dome 1,2 2 G SR SR SR 3.3.1.1.9 3.3.1.1.10 3.3.1.1.15
,; 1059.0 psig 4. Reactor Vessel Water Leve I-Low, Level 3 1,2 2 G SR SR SR SR SR 3.3.1.l.1 3.3.1.1.9 3.3.1.1.13 3.3.1.1.15
 
3.3.1.1.17 11.0 inches 5. Main Steam Isolation Valve-Closure 8 F SR SR SR SR 3.3.l.l.9 3.3.1.1.13 3.3.1.1.15
 
3.3.1.1.17
,; 13.7% closed 6. Drywell Pressure High 1,2 G SR SR SR 3.3.1.1.9 3.3.1.1.13 3.3.1.1.15
,; 1.93 psig 7. Scram Discharge Volume Water Level-High
: a.
Unit 1,2 G SR SR SR 3.3.1.l.9 3.3.1.1.13 3.3.1.1.15
,; 767 ft 8.55 inches elevation 5'" 2 H SR SR SR 3.3.1.1.9 3.3.1.1.13 3.3.1.1.15
,; 767 ft 8.55 inches elevation (continued) (a) With any control rod withdrawn from a core cell containing one or fuel LaSalle 1 and 2 3.3.1.1 9 Amendment No. 200 I 187 RPS Instrumentation 3.3.l.1 Table 3.3.1.1 1 (page 3 of 3) Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED ALLO'IlA3LE FUNCT ION CONDITIONS ACTION D. 1 R EQU I R NTS VALUE 7. Scram Discharge Volume Level-High (continued)
Water b. Float Switch 1,2 2 G SR SR SR 3.3.1.1.9 3.3.1.1.13
 
3.3.1.1.15
;; 767 ft 8.55 inches elevation SUd 2 H SR SR SR 3.3.1.1 9 3.3.1.1.13
 
3.3.1.1.15
;; 767 ft 8.55 inches elevation
: 8. Turbine Closure Stop ::, 25% RTP 4 SR SR SR SR SR 3.3.1.1.9 3.3.1.1.13 3.3.1.1.15 3.3.1.1.16 3.3.1.1.17
;; 8.9% closed 9. Turbine Control Valve Fast Closure, Tri p Oi 1 Pressure-Low
::, 25% RTP SR SR SR SR SR 3.3.1.1.9 3.3.1.1.13 3.3 1.1.15 3.3 1.1.16
::, 425.5 psig 10. Reactor Mode SWitch-Shutdown Positi on 1,2 2 G SR SR .1.1.12 3.3.1.1.15 NA 5(a) H SR SR 3. .1.1.12 3.3.1.1.15 NA 11. Manual Scram ,2 G SR SR 3. .1.1.5 3.3.1.1.15 5'" 2 SR SR 3.3.1.1.5 3.3.1.1.15 NA (a) WiUI any control rod witndrawn from a core cell containing one or more fuel assemblies.
LaSalle 1 and 2 3.3.1.1-10 Amendment No. 200 187 
-SRM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION 3.3.1.2 Source Range Monitor (SRM) Instrumentation LCO 3.3.1.2 APPLICABILITY:
The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.According to Table 3.3.1.2-1.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required SRMs 4 hours SRMs inoperable in to OPERABLE status.MODE 2 with intermediate range monitors (IRMs) on Range 2 or below.B. Three required SRMs B.1 Suspend control rod Immediately inoperable in MODE 2 withdrawal.
with IRMs on Range 2 or below.C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B not met.D. One or more required D.1 Fully insert all 1 hour SRMs inoperable in insertable control MODE 3 or 4. rods.AND (continued)
LaSalle 1 and 2 3.3.1.2-1 Amendment No. 147/133 SRM Instrumentation 3.3.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued)
D.2 Place reactor mode 1 hour switch in the shutdown position.E. One or more required E.1 Suspend CORE Immediately SRMs inoperable in ALTERATIONS except MODE 5. for control rod insertion.
AND E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.
LaSalle I and 2 3.3.1.2-2 Amendment No. 147/133 Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS ------NOTE -Refer to Table 3.3.1.2 1 to determine which SRs apply for each applicable MODE or other specified condition.
SURV EI LLANC E FREQUENCY 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Cont ro 1 Program 3.3.1.2.2 Only required to be met during CORE A LT E RA TI 0N S . One SRM may be used to satisfy more than one of the following.
Verify an OPERABLE SRM detector is In accordance located in: with the Surveillance Frequency Control Program The fueled region; The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region; and A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region. In accordance with the Surveillance Frequency Control Program 3.3.1.2.3 Perform CHANNEL CHECK. (continued)
LaSalle 1 and 3.3.1.2-3 Amendment No. 200/ 187 SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS 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.
Veri count rate is: a. 3.0 cps; or b. 0.7 cps with a signal ratio 20:1. to noise In accordance with the Surveillance uency Control Program SR 3.3.1.2.5 The determination of signal to noise ratio is 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.
Perform CHANNEL FUNCTIONAL TEST and determination of signal to noise ratio. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2.6 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. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.3.1.2 4 Amendment No.200 / 187 Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SR 3.3.1.2.7
-------------Neutron detectors are excluded. Not required to be performed until 12 hours after IRMs on Range 2 or below. Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.3.1.2 5 Amendment No. 200 1 187 SRM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page I of 1)Source Range Monitor Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE FUNCTION SPECIFIED CONDITIONS CHANNELS REQUIREMENTS
: 1. Source Range Monitor 2(a) 3 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 includes only that SRM detector.to be OPERABLE during spiral offload or reload when the fueled region (c) Special movable detectors may be used in place of SRMs if connected to normal SRM circuits.LaSalle 1 and 2 3.3.1.2-6 Amendment No. 147/133 OPRM Instrumentation 3.3.1.3 3.3 INSTRUMENTATION 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation LCO 3.3.1.3 APPLICABILITY:
Four channels of the OPRM instrumentation shall be OPERABLE.THERMAL POWER > 25% RTP.ACTIONS-------------------------------------
NOTE -------------------------------------
Separate Condition entry is allowed for each channel.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in 30 days inoperable, trip.A.2 Place associated RPS 30 days trip system in trip.OR A.3 Initiate alternate 30 days method to detect and suppress thermal hydraulic instability oscillations.(continued)
LaSalle 1 and 2 3.3.1.3-1 Amendment No. 177/163 OPRM Instrumentation 3.3.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. OPRM trip capability B.1 Initiate alternate 12 hours not maintained, method to detect and suppress thermal hydraulic instability oscillations.
AND B.2 Restore OPRM trip 120 days capability.
C. Required Action and C.1 Reduce THERMAL POWER 4 hours associated Completion
< 25% RTP.Time not met.LaSalle 1 and 2 3.3.1.3-2 Amendment No. 177/163 OPRM Instrumentation 3.3.1.3 SURVEILLANCE REQUIREMENTS 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 OPRM maintains trip capability.
SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.2 Calibrate the local power range monitors.
In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.3 NOTE------Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.
The setpoints for the trip function shall be as specified in the COLR. SR 3.3.1.3.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.3.1.3 3 Amendment NO.200 / 187 OPRM Instrumentation 3.3.1.3 SURVEILLANCE R IREMENTS SR 3.3.1.3.5 SURVEILLANCE Verify OPRM is not bypassed when THERMAL POWER is 28.1% RTP and recirculation drive flow is < 60% of rated recirculation drive flow. FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.6 Neutron detectors are excluded.
Verify the RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.1.3-4 Amendment No. 200/ 187 Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 APPLICABILITY:
The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.According to Table 3.3.2.1-1.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel 24 hours (RBM) channel to OPERABLE status.inoperable.
B. Required Action and B.1 Place one RBM channel 1 hour associated Completion in trip.Time of Condition A not met.OR Two RBM channels inoperable.
C. Rod worth minimizer C.1 Suspend control rod Immediately (RWM) inoperable movement except by during reactor scram.startup.OR (continued)
LaSalle I and 2 3.3.2.1-1 Amendment No. 147/133
--.Control Rod Block Instrumentation 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)
C.2.1.1 Verify > 12 rods Immediately withdrawn.
OR C.2.1.2 Verify by Immediately administrative methods that startup with RWM inoperable has not been performed in the last 12 months.AND C.2.2 Verify movement of During control control rods is in rod movement compliance with analyzed rod position sequence by a second licensed operator or other qualified member of the technical staff.D. RWM inoperable during D.1 Verify movement of During control reactor shutdown.
control rods is in rod movement compliance with analyzed rod position sequence by a second licensed operator or other qualified member of the technical staff.(continued)
LaSalle 1 and 2 3.3.2.1 -2 Amendment No. 147/133 Control Rod Block Instrumentation 3.3.2.1 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME E. One or more Reactor Mode Switch-Shutdown Position channels inoperable.
E.1 Suspend control rod withdrawal.
Immediately E.2 Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assembl i es. Immediately SURVEILLANCE REQUIREMENTS NOTES Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function. When an RBM 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 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.3.2.1 3 Amendment No. 200/ 187 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.1.2
---NOTE Not required to be performed until after any control rod is withdrawn 10% RTP in MODE 2. 1 hour at Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.3 Not requi red to be performed unti 1 1 hour after THERMAL POWER is 10% RTP in MODE 1. Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.4 Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.3.2.1 4 Amendment No. 200 I 187 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE
! FREQUENCY SR 3.3.2.1.5 Neutron detectors are excluded.
Verify the RBM is not bypassed when In accordance THERMAL POWER is 30% RTP and a with the peripheral control rod is not selected.
Surveillance Frequency Control Program SR 3.3.2.1.6 Verify the RWM is not bypassed when In accordance THERMAL POWER is s 10% RTP. with the Surveillance Frequency Control Program SR
-----------------
NOTE-------------Not required to be performed until 1 hour after reactor mode switch is in the shutdown position.
Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.8 Verify control rod sequences input to the Prior to RWM are in conformance with analyzed rod decl aring RWM position sequence.
OPERABLE following 1 oadi ng of sequence into RWM SR 3.3.2.1.9 Verify the bypassing and position of Prior to and control rods required to be bypassed in during the RWM by a second licensed operator or movement of other qualified member of the technical control rods staff. bypassed in RWM LaSalle 1 and 3.3.2.1 5 Amendment No.200 / 187 Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REOUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REGUIREMENTS VALUE 1. Rod Block Monitor a. Upscale (a) 2 SR 3.3.2.1.1 As specified in SR 3.3.2.1.4 the COLR SR 3.3.2.1.5 b. Inop (a) 2 SR 3.3.2.1.1 NA SR 3.3.2.1.5 c. Downscale (a) 2 SR 3.3.2.1.1
> 1.25S RTP SR 3.3.2.1.4 SR 3.3.2.1.5 2. Rod Worth Minimizer 1 (b), 2 (b) 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8 SR 3.3.2.1.9 3. Reactor Mode Switch -Shutdown (c) 2 SR 3.3.2.1.7 NA Position (a) THERMAL POWER > 30S RTP and no peripheral control rod selected.(b) With THERMAL POWER < 10 RTP.(c) Reactor mode switch in the shutdown position.LaSalle 1 and 2 3.3.2.1-6 Amendment No. 147/133 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 3.3 INSTRUMENTATION 3.3.2.2 Feedwater System and Main Turbine High Water Level Trip Instrumentation LCO 3.3.2.2 APPLICABILITY:
Four channels of feedwater system and main turbine high water level trip instrumentation shall be OPERABLE.THERMAL POWER > 25% RTP.ACTIONS-------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.-----------------------------------------------------------.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more feedwater A.1 Place channel in 7 days system and main trip.turbine high water level trip channels inoperable.
B. Feedwater system and B.1 Restore feedwater 2 hours main turbine high system and main water level trip turbine high water capability not level trip maintained.
capability.(continued)
LaSalle I and 2 3.32.2.-1 Amendment No. 147/133 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 ACTIONS CONDITION REQUI RED ACTION COMPLETION TIME C. Required Action and associated Completion Ti me not met. C.1 ----NOTE-Only applicable if inoperable channel is the result of an inoperable driven feedwater pump breaker or feedwater turbine stop valve. Remove affected feedwater pump(s) from service 4 hours C.2 Reduce THERMAL to < 25% RTP. POWER 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 feedwater system and main turbine high water level trip capability is maintained.
SURVEILLANCE FREQUENCY SR 3.3.2.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.3.2.2-2 Amendment No. 2001 187 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2.3 Perform CHANNEL CALIBRATION.
The Allowable Value shall be s 59.5 inches. In accordance with the Surveillance uency Control Program SR 3.3.2.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker and valve actuation.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.2.2-3 Amendment No.2001 187 PAM Instrumentation 3.3.3.1 3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3.1 The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be OPERABLE.APPLICABILITY:
MODES I and 2.ACTIONS------------------------------------
NOTE-------------,.
-....Separate Condition entry is allowed for each Function.
I... ---. .-----.--...-
.--...-....--..-...-....--..--...--.
.......-----..-...-
--...----...----.-.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore required 30 days with one required channel to OPERABLE channel inoperable.
status.B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A Specification 5.6.6.not met.C. One or more Functions C.1 Restore one required 7 days with two required channel to OPERABLE channels inoperable.
status.(continued)
LaSalle 1 and 2 3.3 ,3.1-1 Amendment No. lit/157 4 PAM Instrumentation 3.3.3.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3.1-1 for not met. the channel.E. As required by E.1 Be in MODE 3. 12 hours Required Action D.1 and referenced in Table 3.3.3.1-1.
F. As required by F.1 Initiate action in Immediately Required Action D.1 accordance with and referenced in Specification 5.6.6.Table 3.3.3.1-1.
LaSalle 1 and 2 3.3.3.1- 2 Amendment No. 147/133 Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS NOTES These SRs apply to each Function in Table 3.3.3.1 1. 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 other required channel in the associated Function is OPERABLE.
SURVEI LLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Contro 1 Program SR 3.3.3.1.2 (Deleted)
SR 3.3.3.1.3 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.3.3.1-3 Amendment No.2001 187 PAM Instrumentation 3.3.3.1 Table 3.3.3.1-I (page I of 1)Post Accident Monitoring Instrumentation CONDIT IOnS REFERENCED REQUIRED FROH REQUIRED FVNCTION CHANNELS ACTION D.1 1. Reactor Steam Dome Pressure 2 E 2. Reactor Vessel Water Level a. Fuel Zone 2 .E b. Wide Range 2 E 3. Suppression Pool Water Level 2 E 4. Drywell Pressure a. Narrow Range 2 E b. Wide Range 2 E 5. PrImary Containment Gross Gamma Radiation 2 F 6. Penetration Flow Path PCIV Position 2 per penetration
&#xa3;flow pathI&M" 7. (Deleted)S. (Deleted)9. Suppression Pool Water Temperature 2 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.I I LaSal le I and 2 3 .3.3.1-4 Amendment NO. 172 /158
--Remote Shutdown Monitoring System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown Monitoring System LCO 3.3.3.2 APPLICABILITY:
The Remotie Shutdown Monitoring System Functions shall be OPERABLE.MODES 1 and 2.ACTIONS Separate Condition entry is allowed for each Function.---- --- ---- --- --.-- .-.- ...--......-- ...-. -.-....-- .:-- ---CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required 30 days Functions inoperable.
Function to OPERABLE status.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met.LaSalle 1 and 2 3.3.3.2-1 Amendment No.111/157 Remote Shutdown Monitoring System 3.3.3.2 SURVEILLANCE REQUIREMENTS NOTE When an instrumentation 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. SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
In accordance with the Surveillance Frequency Control Program SR 3.3.3.2.2 Perform CHANNEL CALIBRATION for each required instrumentation channel. In accordance with the Surveillance uency Control Program LaSalle 1 and 2 3.3.3.2 2 Amendment No .200 / 187 EOC-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)
Instrumentation LCO 3.3.4.1 a. Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE: 1. Turbine Stop Valve (TSV)- Closure: and 2. Turbine Control Valve (TCV) Fast Closure, Trip Oil Pressure-Low.OR b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)L" limits for inoperable EOC-RPT as specified in the COLR are made applicable.
APPLICABILITY:
THERMAL POWER > 25% RTP with any recirculation pump in fast speed.ACTIONS-------------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.----------.-- --------. ------.- --------------------.- ----..- ---------CONDITION REOUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore channel to 72 hours channels inoperable.
OPERABLE status.OR (continued)
LaSalle I and 2 3.3.4. 1-1 Amendment No. 147/133 EOC-RPT Instrumentation 3.3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2 --------NOTE---------
Not applicable if inoperable channel is the result of an inoperable breaker.Place channel in 72 hours trip.B. One or more Functions B.1 Restore EOC-RPT trip 2 hours with EOC-RPT trip capability.
capability not maintained.
OR AND B.2 Apply the MCPR limit 2 hours for inoperable MCPR limit for EOC-RPT as specified inoperable EOC-RPT not in the COLR.made applicable.
C. Required Action and C.1 Remove the associated 4 hours associated Completion recirculation pump Time not met. fast speed breaker from service.OR C.2 Reduce THERMAL POWER 4 hours to < 25% RTP.LaSalle I and 2 3.3.4.1- 2 Amendment No. 147/133 EOC RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS
----NOTE When a channel is placed in an inoperable status solely for performance of required Surveillances.
entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains EOC-RPT trip capability.
SR 3.3.4.1.1 SURVEI LLANCE Perform CHANNEL FUNCTIONAL TEST. FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.2 Perform CHANNEL CALIBRATION.
The Allowable Values shall be: a. TSV-Closure: 8.9% closed; and b. TCV Fast Closure, Trip Oil Pressure-Low: 425.5 psig. In accordance with the Surveillance uency Control Program SR 3.3.4.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation.
In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.4 Verify TSV-Closure and TCV Fast Closure, Trip Oil Pressure-Low Functions are not bypassed when THERMAL POWER is 25% RTP. In accordance with the Surveillance Frequency Control Program (continued)
LaSall eland 2 3.3.4.1 3 Amendment No. 200/187 EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS SR 3.3.4.l.5 SURVEILLANCE ------------------
NOTE Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.l.6.
FREQUENCY Verify the EOC-RPT is within limits. SYSTEM RESPONSE TIME In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.6 Determine RPT time. breaker arc suppression In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.4.1 4 Amendment No .200 I 187 ATWS-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT)
Instrumentation LCO 3.3.4.2 Two channels per trip system for each ATWS-RPT instrumentation Function listed below shall be OPERABLE: a. Reactor Vessel Water Level -Low Low. Level 2; and b. Reactor Steam Dome Pressure-High.APPLICABILITY:
MODE 1.ACTIONS--------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 14 days inoperable.
OPERABLE status.OR A.2 --------NOTE---------
Not applicable if inoperable channel is the result of an inoperable breaker.Place channel in 14 days trip.(continued)
LaSalle 1 and 2 3.3.4.2-1 Amendment No. 147/133 ATWS-RPT Instrumentation 3.3.4.2 ACTIONS CONDITION REHUIRED ACTION COMPLETION TIME B. One Function with B.1 Restore ATWS-RPT trip 72 hours ATWS-RPT trip capability.
capability not maintained.
C. Both Functions with C.1 Restore ATWS-RPT trip 1 hour ATWS-RPT trip capability for one capability not Function.maintained.
D. Required Action and D.1 Remove the associated 6 hours associated Completion recirculation pump Time not met. from service.OR D.2 Be in MODE 2. 6 hours La~alle I and 2 3.3.4.2 -2 Amendment No. 147/133 ATWS RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS
-NOTE ---------------
When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability.
SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.3 Perform CHANNEL CALIBRATION.
The Allowable Values shall be: a. Reactor Vessel Water Level-Low Low, Level 2: 54 inches; and b. Reactor Steam Dome Pressure-High:
s 1147 psig. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.4.2-3 Amendment No.200 / 187 
---ECCS Instrumentation 3.3.5.1 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation LCO 3.3.5.1 APPLICABILITY:
The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE.According to Table 3.3.5.1-1.
ACTIONS-------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable.
referenced in Table 3.3.5.1-1 for the channel.(continued)
LaSalle 1 and 2 3.3.5.1-1 Amendment No. 147/133 ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION I REQUIRED ACTION COMPLETION TIME 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 l.a. 1.b, 2.a and 2.b.Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.
AND B.2--------NOTES--------
: 1. Only applicable in MODES 1. 2.and 3.1 hour from discovery of loss of initiation capability for feature(s) in both divisions 1 hour from discovery of loss of HPCS initiation capability 24 hours 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.(continued)
LaSalle 1 and 2 3.3.5.1-2 Amendment No. 147/133 ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 --- NOTES--------
Required Action A.1 1. Only applicable and referenced in in MODES 1, 2, Table 3.3.5.1-1.
and 3.2. Only applicable for Functions 1.c and 2.c.Declare supported 1 hour from feature(s) inoperable discovery of when its redundant loss of feature ECCS initiation initiation capability capability for is inoperable.
feature(s) in both divisions AND C.2 Restore channel to 24 hours OPERABLE status.(continued)
LaSalle I and 2 3.3.5.1-3 Amendment No. 147/133 ECCS Instrumentation 3.3.5.1 I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required Action A.1 and referenced in Table 3.3.5.1-1.
D.1--------NOTES--------
: 1. Only applicable in MODES 1, 2.and 3.2. Only applicable for Functions I.d. i.e. 1.f.1.g, 2.d. 2.e.and 2.f.Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.
AND D.2--------NOTE---------
Only applicable for Functions 1.d and 2.d.1 hour from discovery of loss of initiation capability for feature(s) in both divisions 24 hours from discovery of loss of initiation capability for feature(s) in one division (continued)
Declare supported feature(s) inoperable.
AND LaSalle I and 2 3.3.5.1 -4 Amendment No. 147/133 ECCS Instrumentation 3.3.5.1 I U ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME 4 I D. (continued)
D.3--------NOTE---------
Only applicable for Functions 1.g and 2.f.Restore channel to OPERABLE status.24 hours 7 days AND D.4 Restore channel to OPERABLE status.E. As required by Required Action A.1 and referenced in Table 3.3.5.1-1.
E.1 Declare Automatic Depressurization System (ADS) valves inoperable.
AND E.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 (continued)
LaSalle I and 2 3.3.5.1-5 Amendment No. 147/133 ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. As required by F.1 --------NOTE---------
Required Action A.1 Only applicable for and referenced in Functions 4.c, 4.e, Table 3.3.5.1-1.
4.f, 4.g. 5.c. 5.e.and 5.f.Declare ADS valves 1 hour from inoperable.
discovery of loss of ADS initiation capability in both trip systems AND F.2 Restore channel to 96 hours from OPERABLE status. discovery of inoperable channel concurrent with HPCS or RCIC inoperable AND 8 days G. Required Action and G.1 Declare associated Immediately associated Completion supported feature(s)
Time of Condition B. inoperable.
C, D, E. or F not met.LaSalle 1 and 2 3.3.5. 1-6 Amendment No. 147/133 ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS NOT E S -----------------------------------Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function. 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.d, 3.e, and 3.f; and (b) for up to 6 hours for Functions other than 3.c, 3.d, 3.e, and 3.f, provided the associated Function or the redundant Function maintains ECCS initiation capability.
SURVEILLANCE FREQUENCY SR 3.3.5.l.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.l.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.l.3 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.5.l.4 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.3.5.1-7 Amendment No. 200/ 187 ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.3.5.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.6 Verify ECCS RESPONSE TIME is within limits. In accordance with the Survei 11 ance Frequency Control Program LaSalle 1 and 2 3.3.5.1 8 Amendment No. 2001 187 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 4) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTI ON CONDITIONS FUNCTION ACTION A.l REQU I REMENTS VALUE 1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS) Subsystems
: a. Reactor Vessel Water Level-Low Low Low, Leve I 1 1.2.3. 2(0) B SR SR SR SR SR 3.3.5.1.1 3.3.5.1.2 3..5.1.4 3.3.5.1.5 3.3.5.1.6
;:> -147.0 inches b. Drywell Pressure-High 1.2,3 2\b) SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6
,,1.77psig
: c. LPCI Pump A Start-Time Delay Relay 1,2,3. C SR SR SR 3.3.5.1.2 3.3..1.4 3.3.5.1.5 " 5.5 seconds d. Reactor Steam Dome Pressure-Low (Injection Permissive) 1.2.3 2 SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6 " 490 Dsig and 522 psig 2 SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6
;:> " 490 psig and 522 psig e. LPCS Pump Discharge Fl (Bypa ss) 1.2,3, SR SR SR 3.3.5.1.2 3.3.5.1.3 3.3.5.1.5
;:> " 1240 gpm 1835 gpm and f. LPCI Pump A Discharge Flow-Low (Bypass) 1,2,3. SR SR SR 3.3.5.1.2 3.3.5.1.3 3.3.5.1.5
;:> " 1330 2144 gpm and gpm g. LPCS and LPCI A Injection Line Pressure-Low (Injection Permissive) 1,2,3 1 per valve D SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6
:> " 490 psig and 522 pSig 1 per valve 3 SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6
;:> 490 psig and 522 psig h. Manual Initiation
: 1. 2,3, c SR 3.3.5.1.5 (cont;nued) (al When associated EeCS subsystem(s) are required to be OPEQABLE per LCD 3.5.2, "EeCS-Shutdown." (b) Also required to initiate the associated diesel generator (DG). LaSalle 1 and 2 3.3.5.1-9 Amendment No.200 / 187 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1*1 (page 2 of 4) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FRO!' SPEcrcIED CHANNELS PER REQUIRED SURVEI LLANCE ALLOWABLE FUNCTION CONDIT IONS FUNCT:ON ACT ION A. 1 REQUIREMENTS VALUE 2. LPCI 3 and Suo systems LPCI C a. Reactor Vessel Water Level Low Low Low, Leve I 1 1.2,3, SR SR SR SR SR 3.3.5.1.1 3.3.5.1.2 3.3,5.1.4 3.3.5.1.5 3.3.5 1.6 :? -147.0 inches b. Drywell Pressure-High 1.2,3 2'" SR SR SR SR 3.3.5.1.2 3,3.5.1.4 3.3.5.1.5 3.3.5.1.6
: 1. 77 pSig c. LPCl Pump B Start-Time Delay Relay 1.2,3, c SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3,5.1.5
$ 5.5 seconds d. Reactor Steam Dome Pressure-LoVi (Injection Permissive) 1.2.3 SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6
:? 490 psig and $ 522 pS i 9 2 SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5 1.5 3.3.5.1.6
:? 490 psig and $ 522 psig e. LPCI Pump Band LPCI Pump C Discharge Flow-Low (Bypass) 1,2,3, 1 per' pump SR SR SR 3.3.5.1.2 3.3.5.1.3 3.3.5.1.5
:? 1330 gpm and $ 2144 gpm f. LPCI 8 and LPCI Injection Line Pressure-Low (Injection Permissive) 1.2.3 1 per valve o SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 3.3.5.1.6
:? 490 psig and $ 522 psig 4(') ,5") 1 per val ve 8 SR SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5,1.5 3.3.5.1.6
:? 490 psig and $ 522 psig g. Manual Initiation 1,2.3, c SR 3.3.5.1.5 NA (continued) (a) When associated ECCS subsystem(s) are required to be OPERA3LE per LCD 3.5.2. (bl Also required to initiate the associated DG. LaSalle 1 and 2 3.3.5.1 10 Amendment No.200 / 187 ECCS Instrumentation 3.3.5.1 Table 3 3.5.1 1 (page 3 of 4) Emergency Core Cooling
:nstrumentation APPLICABLE CONDITIONS r1CDES OR REFERENCED O,HER REQUIREC FROM SPECIFIED CHMNELS PER REQUIRED SURVE I LLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A. 1 REQUIREMENTS VALUE High Pressure Core Spray (HPCS) 5ysten' Reactor Vessel Water 1,2,3, SR 3.3.5.1.1 " -83 inches Level-Low Low, SR 3.3.5.1.2 Leve1 2 SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6 Drywel I Pressure-High 1,2,3 SR 3.3.5.1.2
<; 1. 77 psig SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6 Reactor Vessel Water 1,2,3, c SR 3.3.5.1.1 " 66.5 inches Level 8 SR SR SR
: d. Discharge o SR 3.3.5.1.2 13.2 pSig gh SR (Bypass) SR HPCS System Flow 1,2,3, C SR 3.3.5.1.2 2 1380 gpm and (Bypass) SR 3.3.5.1.3
<; 2194 gpm SR 3.3.5.1.5 ,nitiation 1,2,3, C SR 3.3.5.1.5 NA Automatic System (ADS Reactor Vessel Water SR 3.3.5.1.1
> 147.0 Level-Low Low Low, SR 3.3.5.1.2 inches Leve I 1 SR 3.3.5.1.4 3.3.5.1.5 Drywell Pressure-High E SR 3.3.5.1.2
,,;1.77 psig SR 3.3.5.1.4 SR 3.3.5.1.5 ADS Initiation Timer F SR 3.3.5.1.2 " ::8 seconds SR 3.3.5.1.4 SR 3.3.5.1.5 (conti nued) (0) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2. (bl Also required to initiate the associated CG. (c) With reactor steam dome pressure>
150 psig. LaSalle 1 and 3.3.5.1-11 Amendment No. 200' 187 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1*1 (page 4 of 4) Emergency Core Cooling System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCED FROM REQUIRED ACTION A.l SURVEI LLANC E REQUIREMENTS ALLOWABLE VALUE 4. ADS Tri p System A (continued)
: d. Reactor Vessel Water Leve l-Low. Level 3 (Confi rmatory) 1,2 (rl ,3(c) SR SR SR SR 3.3.5.1.1 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 11.0 inches e. LPCS Pump Discharge Pressure-High 1,2 (el ,3(c) SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 " 131.2 and " 271.0 psig psig f. LPCI Pump A Discharge Pressure-High 1 ,2 (e) ,3(c) SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 105.0 psig and " 128.6 ps i g g. ADS Drywell Pressure Bypass Timer 1.2 I c}.3 Ic ) SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 598 seconds h. Manual Initiation
: 1. 21e) .3Ie) SR 3.3.5.1.5 NA 5. ADS Trip System B a. Reactor Vessel Water Level-Low Low Low. Level 1 1 ,2 (e) ,3(C) SR SR SR SR 3.3.5.1.1 3.3.5.1.2 3.3.5.1.4
 
3.3.5.1.5 " -147.0 inches b. Drywell Pressure-High 1 ,2 (el ,3(C) SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 1.77 psig c. ADS Initiation Timer 1.2 Ie) .3Ie) SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 118 seconds d. Reactor Vessel Water Level-Low.
Level 3 (Confirmatory) 1 .2 Ie) .3Ie) SR SR SR SR 3.3.5.1.1 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 11.0 inches e. LPCI Pumps B & C Discharge Pressure-High 1 ,2{c) ,3(c) 2 per pump SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5 " 105.0 psig and " 128.6 psig f. ADS Drywell Pressure Bypass Timer 1. 2{c) ,3(c) SR SR SR 3.3.5.1.2 3.3.5.1.4 3.3.5.1.5
" 598 seconds g. Manual Initiation 1.2(c) .3(c) SR 3.3.5.1.5 NA (c) With reactor steam dome pressure>
150 psig. LaSalle 1 and 2 3.3.5.1-12 Amendment No. 200/ 187 
-RCIC System Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.2 APPLICABILITY:
The RCIC System instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.MODE 1.MODES 2 and 3 with reactor steam dome pressure > 150 psig.ACTIONS-------------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable.
referenced in Table 3.3.5.2-1 for the channel.B. As required by B.1 Declare RCIC System 1 hour from Required Action A.1 inoperable.
discovery of and referenced in loss of RCIC Table 3.3.5.2-1.
initiation capability AND B.2 Place channel in 24 hours trip.(continued)
LaSalle 1 and 2 3.3.5.2-1 Amendment No. 147/133 RCIC System Instrumentation 3.3.5.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Restore channel to 24 hours Required Action A.1 OPERABLE status.and referenced in Table 3.3.5.2-1.
D. As required by D.1 --------NOTE---------
Required Action A.1 Only applicable if and referenced in RCIC pump suction is Table 3.3.5.2-1.
not aligned to the suppression pool.Declare RCIC System 1 hour from inoperable.
discovery of loss of RCIC initiation capability AND D.2.1 Place channel in 24 hours trip.OR D.2.2 Align RCIC pump 24 hours suction to the suppression pool.E. Required Action and E.1 Declare RCIC System Immediately associated Completion inoperable.
Time of Condition B.C, or D not met.LaSalle 1 and 2 3.3.5.2- 2 Amendment No. 147/133 RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS NOTES Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function. 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 4; and (b) for up to 6 hours for Functions 1 and 3 provided the associated Function maintains RCIC initiation capability.
SURVEI SR 3.3.5.2.1 Perform CHANNEL In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 Perform CHANNEL In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.4 Perform LOGIC SYSTEM FUNCTIONAL In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.3.5.2-3 Amendment No .200 / 187 RCIC System Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page I of 1)Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED FROM CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCTION ACTION A.1 RECUIREMENTS VALUE 1. Reactor Vessel Water 4 B SR 3.3.5.2.2
> -83 inches Level -Low Low. Level 2 SR 3.3.5.2.3 SR 3.3.5.2.4 2. Reactor Vessel Water 2 C SR 3.3.5.2.1
< 66.5 inches Level -High. Level 8 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 3. Condensate Storage Tank 2 D SR 3.3.5.2.2
> 713.6 ft Level -Low SR 3.3.5.2.3 SR 3.3.5.2.4 4. Manual Initiation 1 C SR 3.3.5.2.4 NA LaSalle 1 and 2 3.3.5.2-4 Amendment No. 147/133 Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 APPLICABILITY:
The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.According to Table 3.3.6.1-1.
ACTIONS------------------------------------
NOTES------------------------------------
: 1. Separate Condition entry is allowed for each channel.2. For Function I.e. when automatic isolation capability is inoperable for required Reactor Building Ventilation System corrective maintenance, filter changes, damper cycling, or required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 4 hours.3. For Function I.e. when automatic isolation capability is inoperable due to loss of reactor building ventilation or for performance of SR 3.6.4.1.3 or SR 3.6.4.1.4, entry into associated Conditions and Required Action may be delayed for up to 12 hours.CONDITION REQUIRED ACTION COMPLETION TIME A. One or-more channels A.1 Place channel in 12 hours for inoperable.
trip. Functions 2.b, 2.f, and 5.a AND 24 hours for Functions other than Functions 2.b.2.f. and 5.a (continued)
LaSalle I and 2 3.3.6.1-1 Amendment No. 147/133 Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or more automatic B.1 Restore isolation 1 hour Functions with capability.
isolation capability not maintained.
C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A Table 3.3.6.1-1 for or B not met. the channel.D. As required by D.1 Isolate associated 12 hours Required Action C.1 main steam line and referenced in (MSL).Table 3.3.6.1-1.
OR D.2.1 Be in MODE 3. 12 hours AND D.2.2 Be in MODE 4. 36 hours E. As required by E.1 Be in MODE 2. 6 hours Required Action C.1 and referenced in Table 3.3.6.1-1.
F. As required by F.1 Isolate the affected 1 hour Required Action C.1 penetration flow and referenced in path(s).Table 3.3.6.1-1.(continued)
LaSalle I and 2 3.3.6.1 -2 Amendment No. 147/133 Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME G. As required by G.1 Isolate the affected 24 hours Required Action C.1 penetration flow and referenced in path(s).Table 3.3.6.1-1.
H. Required Action and H.1 Be in MODE 3. 12 hours associated Completion Time of Condition F AND or G not met.H.2 Be in MODE 4. 36 hours OR As required by Required Action C.1 and referenced in Table 3.3.6.1-1.
I. As required by 1.1 Declare associated 1 hour Required Action C.1 standby liquid and referenced in control (SLC)Table 3.3.6.1-1.
subsystem inoperable.
OR I.2 Isolate the Reactor 1 hour Water Cleanup (RWCU)System.(continued)
LaSalle I and 2 3.3.6.1-3 Amendment No. 147/133 Primary Containment Isolation Instrumentation 3.3.6.1 CONDITION REQUIRED ACTION COMPLETION TIME 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. Immediately J.2 Initiate action to isolate the Residual Heat Removal (RHR) Shutdown Cooling (SDC) System. Immediately SURVEILLANCE REQUIREMENTS
--------NOTES Refer to Table 3.3.6.1 1 to determine which SRs apply for each Primary Containment Isolation Function. 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. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.3.6.1 4 Amendment No. 200/ 187 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1.3 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Verify the ISOLATION SYSTEM RESPONSE TIME of the Main Steam Isolation Valves is within limits. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.6.1-5 Amendment No. 200 I 187 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 4)Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REOUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REOUIREMENTS VALUE 1. Main Steam Line Isolation a. Reactor Vessel Water 1.2.3 2 D SR 3.3.6.1.1 Z -137.0 inches Level-Low Low Low. SR 3.3.6.1.2 Level 1 SR 3.3.6.1.4 SR 3.3.6.1.5 b. Main Steam Line 1 2 E SR 3.3.6.1.2 Z 826.5 psig Pressure-Low SR 3.3.6.1.3 SR 3.3.6.1.5 c. Main Steam Line 1,2.3 2 per MSL D SR 3.3.6.1.2 s 128.0 psid Flow-High SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 d. Condenser Vacuum-Low 1 .2C). 2 0 SR 3.3.6.1.2 2 3.8 inches SR 3.3.6.1.4 Hg vacuum 3a) SR 3.3.6.1.5 e. Main Steam Line Tunnel 1.2,3 2 D SR 3.3.6.1.1 s 66.41F Differential SR 3.3.6.1.2 Temperature-High SR 3.3.6.1.4 SR 3.3.6.1.5 f. Manual Initiation 1,2.3 2 G SR 3.3.6.1.5 NA 2. Primary Containment Isolation a. Reactor Vessel Water 1.2.3 2 H SR 3.3.6.1.2 2 -58.0 inches Level-Low Low. SR 3.3.6.1.4 Level 2 SR 3.3.6.1.5 b. Drywell Pressure-High 1,2.3 2 H SR 3.3.6.1.2 s 1.93 psig SR 3.3.6.1.4 SR 3.3.6.1.5 c. Reactor Building 1.2.3 2 F SR 3.3.6.1.1 s 42.0 mR/hr Ventilation Exhaust SR 3.3.6.1.2 Plenum Radiation-High SR 3.3.6.1.4 SR 3.3.6.1.5 d. Fuel Pool Ventilation 1.2.3 2 F SR 3.3.6.1.1 s 42.0 mR/hr Exhaust SR 3.3.6.1.2 Radiation-High SR 3.3.6.1.4 SR 3.3.6.1.5 (continued)
I I (a) With any turbine stop valve not closed.LaSalle 1 and 2 3.3.6.1- 6 Amendment No./ 169, 155 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 4)Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 2. Primary Containment Isolation (continued)
: e. Reactor Vessel Water Level-Low Low Low, Level I f. Reactor Vessel Water Level-Low, Level 3 g. Manual Initiation
: 3. Reactor Core Isolation Cooling (RCIC) System Isolation 1,2,3 1,2,3 1,2,3 2 2 F SR SR SR SR F SR SR SR SR 3.3.6.1.1 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5 3.3.6.1.1 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5-137.0 inches 11.0 inches 1 G SR 3.3.6.1'.5 NA a. RCIC Steam Line Flow-High b. RCIC Steam Line Flow-Timer
: c. RCIC Steam Supply Pressure-Low
: d. RCIC Turbine Exhaust Diaphragm Pressure-High
: e. RCIC Equipment Room Temperature-High
: f. RCIC Equipment Room Differential Temperature-High
: g. RCIC Steam Line Tunnel Temperature-High
: h. RCIC Steam Line Tunnel Differential Temperature-High
: i. Drywell Pressure-High 1,2,3 1,2,3 1.2.3 1,2,3 1,2,3 1.2,3 1,2.3 1,2,3 1.2.3 1 .F SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 2 F SR SR SR 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5 F SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5>_ 58.2 psig 176.0 inches water 2.6 seconds and: 5.5 seconds 5 300 inches water I F SR SR SR SR SR SR SR SR SR SR SR SR 3.3.6.1.1 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5 3.3.6.1.1 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5 3.3.6.1.1 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5 3.3.6.1.1 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5 3.3.6.1.2 3.3.6.1.4 3.3.6.1.5:5 297.01F:s 188.0*F 5 267.0*F-q 163.6-F 1 F SR SR SR SR F SR SR SR 1.77 psig (continued)
LaSalle 1 and 2 3.3.6.1-7 Amendment No. /182/169 K)j Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 4)Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED
* OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTION C.1 REQUIREMENTS VALUE 3. RCIC System Isolation (continued)
J. Manual Initiation 1,2,3 l(h)G SR 3.3.6.1.5 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 3.3.6.1.4 SR 3.3.6.1.5 S 82.8 gpm b. Differential Flow-Timer 1.2.3 I c. RWCU Heat Exchanger Area Temperature-High
: d. RWCU Heat Exchanger Area Ventilation Differential Temperature-High
: e. RWCU Pump and Valve Area Temperature-High
: f. RWCU Pump and Valve Area Differential Temperature-High
: g. RWCU Holdup Pipe Area Temperature-High
: h. RWCU Holdup Pipe Area Ventilation Differential Temperature-High
: i. RWCU Filter/Demineralizer Valve Room Area Temperature-High J. RWCU Filter/Demineralizer Valve Room Area Ventilation Differential Temperature-High 1.2.3 1,2,3 1,2.3 1.2.3 1.2,3 1,2.3 1,2,3 1.2,3 1 per area 1 per area I per area 1 per area I I 1 1 F SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 S 48.9 seconds 5 157.0 0 F I s5 3B;5&deg;F S 209.0 0 F S 91.0'F s 209.0 0 F I S 91.0'F s 209.06F I I I s 91.0'F (continued)(b) Only inputs into one of two trip systems.LaSalle 1 and 2 3.3.6.1-8 Amendment No. 166/152 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 4) Primary Containment Isolation Instrumentation FUNn I ON APPLICABLE MODES OR OTHER SPECIFIEO eONO IT IONS REOUIRED CHANNELS PER TRI P SYSTEM CONDITIONS REFERENCED FROM REOUIRED ACTION C.I SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE 4. RWCU System Isolation (cont.inued)
: k. Reactor Vessel Level-Low Low, LeveI 2 Water 1 ,2,3 SR SR SR 3 .3 .6. 3. .J 6 3 . 3 . 6 . 2 .4 . 5  *58.0 inches 1. Standby Liquid Control Sy s t em Initiation I ,2,3 21tJ) SR 3 . .\.6. .5 NA m. Manual InitIation 1, (' ,3 G SR 336 1 5 NA 5. RHR Shutdown Cooling Syst.em IsolatIon
: a. Reactor Vessel Wate,' Level-Low, Level 3
\,4,0 (" c : SR SR SR SR 3 1. 6. \. 3. 6 .3 J .6. .3. 6 . 1 .2
.4  11 .f) Inches b. Reactor Vessel Pressure-High I ,2, .3 SR SR SR 3 . .\ . 6 .3 .3 .6 3. 3 .6. .2 .4 .5 5 143 psig C. Manual Initiation 1 ,2, :1 G SR 3. 3. 6. 5 NA (b) Only input.s int.o one of t.wo trip systellls. (e) Only one t ri ps y s t em r-e qu i r-e o in MODES 4 and 5 with RHR Shutdown Cooling System integrity mo i n t a t ned . LaSalle 1 and 2 3.3.6.1-9 Amendment No. 197/184 Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION 3.3.6.2 Secondary Containment Isolation Instrumentation LCO 3.3.6.2 APPLICABILITY:
The secondary containment isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.According to Table 3.3.6.2-1.
ACTIONS-------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in 12 hours for inoperable.
trip. Function 2 AND 24 hours for Functions other than Function 2 B. One or more Functions B.1 Restore isolation 1 hour with isolation capability.
capability not maintained.(continued)
LaSalle 1 and 2 3.3.6.2-1 Amendment No. 147/133 Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1.1 Isolate the 1 hour associated Completion associated Time not met. penetration flow path(s).OR C.1.2 Declare associated 1 hour secondary containment isolation valve(s)inoperable.
AND C.2.1 Place the associated 1 hour standby gas treatment (SGT) subsystem(s) in operation.
OR C.2.2 Declare associated 1 hour SGT subsystem(s) inoperable..LaSalle 1 and 2 3.3.6.2- 2 Amendment No. 147/133 Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS
--NOTES Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function. 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.
SURV EI LLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.3 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSall eland 3.3.6.2 3 Amendment No.200 I 187 Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)Secondary Containment Isolation Instrumentation APPLICABLE MODES AND REOUIRED OTHER CHANNELS SPECIFIED PER TRIP SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM REOUIREMENTS VALUE 1. Reactor Vessel Water 1.2.3.(a) 2 SR 3.3.6.2.2
> -58.0 inches Level -Low Low. Level 2 SR 3.3.6.2.3 SR 3.3.6.2.4 2. Drywell Pressure -High 1.2.3 2 SR 3.3.6.2.2
< 1.93 psig SR 3.3.6.2.3 SR 3.3.6.2.4 3. Reactor Building 1.2.3. 2 SR 3.3.6.2.1
< 42.0 mR/hr Ventilation Exhaust Plenum (a).(b) SR 3.3.6.2.2 Radiation
-High SR 3.3.6.2.3 SR 3.3.6.2.4 4. Fuel Pool Ventilation 1.2.3. 2 SR 3.3.6.2.1
< 42.0 mR/hr Exhaust Radiation
-High (a).(b) SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 5. Manual Initiation 1.2.3. 1 SR 3.3.6.2.4 NA (a).(b)(a) During operations with a potential for draining the reactor vessel.(b) During CORE ALTERATIONS.
and during movement of irradiated fuel assemblies in the secondary containment.
LaSalle 1 and 2 3.3.6.2-4 Amendment No. 147/133 CRAF System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Control Room Area Filtration (CRAF) System Instrumentation LCO 3.3.7.1 APPLICABILITY:
Two channels per trip system for the Control Room Air Intake Radiation -High Function shall be OPERABLE for each CRAF subsystem.
MODES 1. 2. and 3.During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS, During operations with a potential for draining the reactor vessel (OPDRVs).ACTIONS-------------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each channel.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Declare associated 1 hour from inoperable.
CRAF subsystem discovery of inoperable.
loss of CRAF subsystem initiation capability AND A.2 Place channel in 6 hours trip.(continued)
LaSalle I and 2 3.3.7.1 -1 Amendment No. 147/133 CRAF System Instrumentation 3.3.7.1 ACTIONS CONDITION REQU I RED ACTION COMPLETION TIME B. Required Action and associated Completion Time not met. B.1 Place the associated CRAF subsystem in the pressurizaton mode of operation.
1 hour B.2 Declare associated CRAF subsystem inoperable.
1 hour 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 CRAF subsystem initiation capability.
SURV EI LLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.3.7.1 2 Amendment No. 200 / 187 CRAF System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1.3 Perform CHANNEL CALIBRATION.
The Allowable Value shall be 11.0 mR/hr. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.7.1-3 Amendment No *200 I 187 LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 APPLICABILITY:
The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.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 A.1 Place channel in 1 hour inoperable.
trip.B. Required Action and B.1 Declare associated DG Immediately associated Completion inoperable.
Time not met.LaSalle I and 2 3.3.8.1 -1 Amendment No. 147/133 Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS -------------------------------------
NOTES----------------------------------Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function. 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 LOP initiation capability.
SURV E ILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.2 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.3 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.4 Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.3.8.1-2 Amendment No.200 / 187 FUNCTION l. Divisions
: 1. 2 and Opposite Unit Division 2-4.16 kV Emergency Bus Undervoltage
: a. Loss of Voltage -4.16 kV Basis b. Loss of Voltage-Time Delay c. Degraded Voltage-4.16 kV Basis d. Degraded Voltage -Time Delay, No LOCA e. Degraded Voltage -Time Delay, LOCA 2. Division 3*4.16 kV Emergency Bus Undervoltage
: a. Loss of Voltage -4.16 kV Basis b. Loss of Voltage-Time Delay c. Degraded Voltage-4.16 kV Basis d. Degraded Voltage -Time Delay, No LOCA e. Degraded Voltage -Time De 1 ay, LOCA (a J In MODES 4 and 5' when associated Shutdown." (b) With no fuel in the reactor vessel, LaSalle 1 and 2 Table 3.3.8.1 1 (page 1 of 1) Loss of Power Instrumentation REQUIRED CHANNELS PER SURVEILLANCE DIVISION REQUIREMENTS SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.5 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3. 3. 8. 1. 5 SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.5 SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.5 2( al (bl SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.5 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.5 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.5 SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3. 3. 8. 1. 5 SR 3.3.8.1.1 SR 3. 3. 8. 1. 2 SR 3.3.8.1.5 2(d)(b) SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.5 ECCS subsystem(s) are required not required to be OPERABLE.
3.3.8.1-3
<: <: <: <: ,; <: <: ,; <: <: ,; <: LOP Instrumentation 3. 3. 8.1 ALLOWABLE VALUE 2870 V and ,; 3127 v 3. 1 seconds and ,; 10.9 seconds 3814 v and ,; 3900 v 270.1 seconds and 329.9 seconds 9.4 seconds and ,; 10.9 seconds 2725 V and ,; 3172 v 10.9 seconds 3814 v and ,; 3900 v 270.1 seconds and 329.9 seconds 9.4 seconds and ,; 10.9 seconds to be OPERABLE per LCO 3.5.2, "ECCS-Amendment No. 209, 196 RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 APPLICABILITY:
Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply.MODES 1. 2, and 3, MODES 4 and 5 with residual heat removal (RHR) shutdown cooling (SDC) isolation valves open, MODE 5. with any control rod withdrawn from a core cell containing one or more fuel assemblies, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS, During operations with a potential for draining the reactor vessel (OPDRVs).ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours power supplies with inservice power one electric power supply(s) from monitoring assembly service.inoperable.
B. One or both inservice B.1 Remove associated 1 hour power supplies with inservice power both electric power supply(s) from monitoring assemblies service.inoperable.(continued)
LaS~alle 1 and 2 3.3.8.2 -1 Amendment No. 147/133 RPS Electric Power Monitoring 3.3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.D. Required Action and D.1 Initiate action to Immediately associated Completion restore one electric Time of Condition A or power monitoring B not met in MODE 4 or assembly to OPERABLE 5 with RHR SDC status for inservice isolation valves open. power supply(s)supplying required instrumentation.
OR D.2 Initiate action to Immediately isolate the RHR SDC System.E. Required Action and E.1 Initiate action to Immediately associated Completion fully insert all Time of Condition A or insertable control B not met in MODE 5 rods in core cells with any control rod containing one or withdrawn from a core more fuel assemblies.
cell containing one or more fuel assemblies.(continued)
LaSalle 1 and 2 3.3.8.2-2 Amendment No.184 '171 RPS Electric Power Monitoring 3.3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1.1 Isolate the Immediately associated Completion associated secondary Time of Condition A or containment B not met during penetration flow movement of irradiated path(s).fuel assemblies in the secondary containment, OR during CORE ALTERATIONS, or during F.1.2 Declare the Immediately OPDRVs. associated secondary containment isolation valve(s) inoperable.
AND F.2.1 Place the associated Immediately standby gas treatment (SGT) subsystem(s) in operation.
OR F.2.2 Declare associated Immediately SGT subsystem(s) inoperable.
LaSalle 1 and 2 3.3.8.2 -3 Amendment No. 147/133 RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 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. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2.2 Perform CHANNEL CALIBRATION.
The Allowable Values shall be: a. Overvoltage s 131.4 V (with time delay set to s 3.92 seconds).
: b. Undervoltage 108.7 V (with time delay set to s 3.92 seconds).
: c. Underfrequency 57.3 Hz (with time delay set to s 3.92 seconds) In accordance with the Surveillance Frequency Control Program SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.8.2-4 Amendment No.200 / 187 Recirculation Loops Operating 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.1 Recirculation Loops Operating LCO 3.4.1 Two recirculation loops with matched flows shall be in operation.
OR One recirculation loop shall be in operation with the following limits 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;c. LCO 3.2.3, "LINEAR HEAT GENERATION RATE (LHGR)," single loop operation limits specified in the COLR;d. LCO 3.3.1.1, "Reactor Protection System (RPS)Instrumentation," Function 2.b (Average Power Range Monitors Flow Biased Simulated Thermal Power -Upscale), Allowable Value of Table 3.3.1.1-1 is reset for single loop operation; and e. LCO 3.3.2.1, "Control Rod Block Instrumentation," Function l.a (Rod Block Monitor -Upscale), Allowable Value of Table 3.3.2.1-1, specified in the COLR, is reset for single loop operation.
APPLICABILITY:
MODES 1 and 2.LaSalle I and 2 3.4.1-1 Amendment No. 177/163 Recirculation Loops Operating 3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No recirculation A.1 Be in MODE 3. 12 hours loops in operation.
B. Recirculation loop B.1 Declare the 2 hours flow mismatch not recirculation loop within limits, with lower flow to be"not in operation." C. Requirements of the C.1 Satisfy the 24 hours LCO not met for requirements of the reasons other than LCO.Condition A or B.D. Required Action and D.1 Be in MODE 3. 12 hours associated Completion Time of Condition C not met.I LaSalle 1 and 2 3.4.1-2 Amendment No. 177/163 Recirculation Loops Operating 3.4.1 SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.1.1 In accordance the Surveillance Frequency Control Program -------------------
NOT E-------------
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: 10% of rated core flow when operating at < 70% of rated core flow; and 5% of rated core flow when operating at 70% of rated core flow. LaSalle 1 and 3.4.1 3 Amendment No. 200/ 187 FCVs 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs) LCO A recirculation loop FCV shall be OPERABLE in each operating recirculation loop.
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 SURVEI SR 3.4.2.1 Verify each FCV fails "as is" on loss of hydraulic pressure at the hydraulic unit.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.4.2-1 Amendment No.200 I 187 FCVs 3.4.2 SURVEILLANCE REQUIREMENTS SR Verify average rate of each FCV movement is: 11% of stroke per second for open i ng; and 11% of stroke per second for closing.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.4.2-2 Amendment NO.200 / 187 Jet Pumps 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.3 Jet Pumps LCO 3.4.3 APPLICABILITY:
All jet pumps shall be OPERABLE.MODES 1 and 2.ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One or more jet pumps A.1 Be in MODE 3. 12 hours inoperable.
LaSalle 1 and 2 3 .4.3-1 Amendment No. 147/133 Jet Pumps 3.4.3 SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.4.3.1 In accordance the Surveillance Frequency Control Program SURVEILLANCE ------NOTES ---Not required to be performed until 4 hours after associated recirculation loop is in operation. 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: Recirculation loop drive flow versus flow control valve position differs by 10% from established patterns. Indicated total core flow versus calculated total core flow differs by 10% from established patterns. Each jet pump diffuser to lower plenum differential pressure differs by 20% from established patterns.
LaSalle 1 and 3.4.3-2 Amendment No. 200 I 187 S/RVs 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 Safety/Relief Valves (S/RVs)LCO 3.4.4 APPLICABILITY:
The safety function of 17 S/RVs for Unit 1, and 12 S/RVs for Unit 2. shall be OPERABLE.MODES 1. 2, and 3.ACTIONS _CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Be in MODE 3. 12 hours S/RVs inoperable.
AND A.2 Be in MODE 4. 36 hours LaSalle 1 and 2 3.4.4- 1 Amendment No. 147/133
--S/RVs 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 Safety/Relief Valves (S/RVs)LCO 3.4.4 APPLICABILITY:
The safety function of 12 S/RVs shall be OPERABLE.MODES 1. 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Be in MODE 3. 12 hours S/RVs inoperable.
AND A.2 Be in MODE 4. 36 hours LaSalle 1 and 2 3.4.4-1 Amendment No. 147/133 S/RVs 3.4.4 SURVEILLANCE REOUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 --------------------
NOTE-------------------
Less than or equal to two 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: In accordance with the Inservice Testing Program Number of Unit I S/RVs Setpoint (psig)4 4 4 4 2 1205 1195 1185 1175 1150+/- 36.1+/- 35.8+/- 35.5+/- 35.2+/- 34.5 Number of Unit 2 S/RVs Setpoint (osia)2 3 2 4 2 1205 1195 1185 1175 1150+/- 36.1+/- 35.8+/- 35.5+/- 35.2+/- 34.5 Following testing, lift within +/- 1%.settings shall be LaSalle I and 2 3.4.4 -2 Amendment No. 147/133 RCS Operational LEAKAGE 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.5 RCS Operational LEAKAGE LCO 3.4.5 APPLICABILITY:
RCS operational LEAKAGE shall be limited to: a. No pressure boundary LEAKAGE: b. < 5 gpm unidentified LEAKAGE;c. < 25 gpm total LEAKAGE averaged over the previous 24 hour period; and d. < 2 gpm increase in unidentified LEAKAGE within the previous 24 hour period in MODE 1.MODES 1. 2. and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Unidentified LEAKAGE A.1 Reduce LEAKAGE to 4 hours not within limit. within limits.OR Total LEAKAGE not within limit.B. Unidentified LEAKAGE B.1 Reduce unidentified 4 hours increase not within LEAKAGE increase to limit. within limit.OR (continued)
LaSalle 1 and 2 3.4.5-1.Amendment No. 147/133 RCS Ope rat i ona 1 LEAKAGE 3.4.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)
B.2 Verify source of unidentified LEAKAGE increase is not intergranular stress corrosion cracking susceptible material.
4 hours C. Required Action and associated Completion Time of Condition A or B not met. .QR Pressure boundary LEAKAGE exists. C.1 AND C.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours SURVEI SR 3.4.5.1 Verify RCS unidentified and total LEAKAGE and unidentified LEAKAGE increase are within limits.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.5-2 Amendment No. 2001 187 RCS PIV Leakage 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.6 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.6 APPLICABILITY:
The leakage from each RCS PIV shall be within limit.MODES 1 and 2, MODE 3. except valves in the residual heat removal shutdown cooling flow path when in. or during the transition to or from, the shutdown cooling mode of operation.
ACTIONS---------------------------------
NOTES------------------------------------
: 1. Separate Condition entry is allowed for each flow path.2. Enter applicable Conditions and Required Actions for systems made inoperable by PIVs.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths ------------
NOTE-------------
with leakage from one Each valve used to satisfy or more RCS PIVs not Required Action A.1 and within limit. 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.(continued)
La~alle I and 2 3.4.6-1 Amendment No. 147/133 RCS PIV Leakage 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.1 Isolate the high 4 hours pressure portion of the affected system from the low pressure portion by use of one closed manual deactivated automatic, or check valve.AND A.2 Isolate the high 72 hours pressure portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours LaSalle 1 and 2 3.4.6-2 Amendment No. 147/133 RCS PIV Leakage 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1-------------------
NOTE--------------------
Only required to be performed in MODES 1 and 2.--------------------------------.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 > 950 psig and < 1050 psig.In accordance with the Inservice Testing Program LaJSalle 1 and 2 3.4.6-3 Amendment No. 147/133 RCS Leakage Detection Instrumentation 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.7 RCS Leakage Detection Instrumentation LCO 3.4.7 The following RCS leakage detection instrumentation shall be OPERABLE: a. Drywell floor drain sump flow monitoring system;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 TINE A. Drywell floor drain A.1 Restore drywell floor 30 days sump flow monitoring drain sump flow system inoperable.
monitoring system to OPERABLE status.B. Required drywell B.1 Analyze grab samples Once per atmospheric monitoring of drywell 12 hours system inoperable, atmosphere.(continued)
I LaSalle I and 2 3.4.7-1 Amendment No. Y71/157 3.4.7 RCS Leakage Detection Instrumentation ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Orywell air cooler condensate flow rate monitoring system inoperable. Not applicable when the required drywell atmospheric monitoring system is inoperable.
C.1 Perform SR 3.4.7.1. Once per 8 hours Only applicable when the drywell atmospheric gaseous radiation monitor is the only OPERABLE monitor. O. Drywell floor drain sump flow monitoring system inoperable.
0.1 0.2 AND Analyze grab samples of the drywell atmosphere.
Monitor RCS LEAKAGE by administrative means. Once per 12 hours Once per 12 hours Orywell air cooler condensate flow rate monitoring system inoperable.
0.3.1 Restore drywell floor 7 days drain sump flow monitoring system to OPERABLE status. 0.3.2 Restore drywell air cooler condensate flow rate monitoring system to OPERABLE status. 7 days (contlnued)
LaSalle 1 and 2 3.4.7-2 Amendment No. 204/191 3.4.7 RCS Leakage Detection Instrumentation ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME E. Required drywell atmospheric monitoring system inoperable.
E.1 Restore required drywell atmospheric monitoring system to OPERABLE status. 30 days Drywell air cooler condensate flow rate monitoring system inoperable.
E.2 Restore drywell ai r cooler condensate flow rate monitoring system to OPERABLE status. 30 days F. Required Action and associated Completion Time of Condition A, B, C, D, or E not met. F.1 AND F.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours G. All required leakage detection systems inoperable.
G.1 Enter LCO 3.0.3. Immediately LaSalle 1 and 2 3.4.7-3 Amendment No. 204/191 3.4.7 RCS Leakage Detection Instrumentation SURVEILLANCE REQUIREMENTS
---
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 other required leakage detection instrumentation is OPERABLE.
SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell atmospheric monitoring system. In accordance with the Survei 11 ance Frequency Control Program SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of leakage detection instrumentation.
required In accordance with the Surveillance Frequency Control Program SR 3.4.7.3 Perform CHANNEL CALIBRATION of required leakage detection instrumentation.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.7-4 Amendment No. 204/191 RCS Specific Activity 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.8 RCS Specific Activity LCO 3.4.8 The specific activity of the reactor coolant shall be limited to DOSE EQUIVALENT 1-131 specific activity s 0.2 pCi/gm.APPLICABILITY:
MODE 1, MODES 2 and 3 with any main steam line not isolated.ACTIONS _CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor coolant -- ---NOTE------------
specific activity LCO 3.0.4.c is applicable.
> 0.2 pCi/gm and .............................
s 4.0 pCi/gm DOSE EQUIVALENT 1-131. A.1 Determine DOSE Once per 4 hours EQUIVALENT 1-131.A.2 Restore DOSE 48 hours EQUIVALENT I-131 to within limits.B. Required Action and 8.1 Determine DOSE Once per 4 hours associated Completion EQUIVALENT 1-131.Time of Condition A not met.B.2.1 Isolate all main 12 hours steam lines.Reactor coolant specific activity> 4.0 pCi/gm DOSE EQUIVALENT 1-131.__ (continued)
I LaSalle I and 2 3.4.8-1 Amendment No. /171/157 RCS Specific Activity 3.4.8 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME B. (continued)
B.2.2.1 Be in M8DE 3. 12 hours B.2.2.2 Be in MODE 4. 36 hours SURVEILLANCE SR 3.4.8.1 Only required to be performed in MODE 1. Verify reactor coolant DOSE I 131 specific activity is 0.2 In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.8-2 Amendment No. 200 / 187 RHR Shutdown Cooling System-Hot Shutdown 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown LCO 3.4.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump In operation, at least one RHR shutdown cooling subsystem shall be in operation.
.....-....-------------------
NOTES--------------------------
: 1. Both RHR shutdown cooling subsystems and.recirculation pumps may be not in 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 vessel pressure less than the RHR cut-in permissive pressure.ACTIONS-------------------------------------
NOTE------------------------------------
Separate Condition entry is allowed for each RHR shutdown cooling subsystem.
-- -- -- ....---.---..---......-.--- -- --- -- --- -- -I CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Initiate action to Immediately shutdown cooling restore RHR shutdown subsystems inoperable.
cooling subsystem to OPERABLE status.(continued)
LaSalle 1 and 2 3.4.9-1 Amendment No. /171/157--B ._ n i -.r RHR Shutdown Cooling System- Hot Shutdown 3.4.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2 Verify an alternate 1 hour method of decay heat removal is available for each inoperable RHR shutdown cooling subsystem.
AND A.3 Be in MODE 4. 24 hours B. No RHR shutdown B.1 Initiate action to Immediately cooling subsystem in restore one RHR operation.
shutdown cooling subsystem or one AND recirculation pump to operation.
No recirculation pump in operation.
AND B.2 Verify reactor 1 hour from coolant circulation discovery of no by an alternate reactor coolant method. circulation AND Once per 12 hours thereafter AND B.3 Monitor reactor Once per hour coolant temperature and pressure.LaSalle 1 and 2 3.4.9 -2 Amendment No. 147/133 RHR Shutdown Cooling System-Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SR 3.4.9.1 SR 3.4.9.2 LaSalle 1 and 2 SURVEILLANCE -------------------
NOTE --------------------
Not required to be met until 2 hours after reactor vessel pressure is less than the RHR cut-in permissive pressure.
Verify one RHR shutdown cooling subsystem or recirculation pump is operating. -------------------NOTE--------------------
Not required to be performed until 12 hours after reactor steam dome pressure is less than the RHR cut-in permissive pressure.
Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.4.9-3 Amendment Nos. 214/200 RHR Shutdown Cooling System -Cold Shutdown 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown LCO 3.4.10 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.
------------------
NOTES--------------------------
: 1. Not required to be met during hydrostatic testing.2. Both RHR shutdown cooling subsystems and recirculation pumps may be not in operation for up to 2 hours per 8 hour period.3. 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 A.1 Verify an alternate 1 hour shutdown cooling method of decay heat subsystems inoperable.
removal is available AND for each inoperable RHR shutdown cooling Once per subsystem.
24 hours thereafter (continued)
La~alle 1 and 2 3.4.10-1 Amendment No. 147/133 RHR Shutdown Cooling System-Cold Shutdown 3. 4 .10 ACTIONS CONDITION
: 8. No RHR shutdown cooling subsystem operation.
AND No recirculation in operation.
8.1 in pump 8.2 REQUIRED ACTION Verify reactor coolant circulating by an alternate method. Monitor reactor coolant temperature and pressure.
SURVEILLANCE REQUIREMENTS SR 3.4.10.1 SR 3.4.10.2 SURVEILLANCE Verify one RHR shutdown cooling subsystem or recirculation pump is operating.
Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. COMPLETION TIME 1 hour from discovery of no reactor coolant circulation Once per 12 hours thereafter Once per hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.10-2 Amendment Nos. 214/200 RCS P/T Limits 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.11 RCS Pressure and Temperature (P/T) Limits LCO 3.4.11 APPLICABILITY:
RCS pressure, RCS temperature.
RCS heatup and cooldown rates, and the recirculation pump starting temperature requirements shall be maintained within limits.At all times.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE---------
A.1 Restore parameter(s) to 30 minutes Required Action A.2 within limits..shall be completed if this Condition is AND entered.A.2 Determine RCS is 72 hours acceptable for continued Requirements of the operation.
LCO not met in MODE 1.2. or 3.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A AND not met.B.2 Be in MODE 4. 36 hours (continued)
LaSalle I and 2 3.4.11-1 Amendment No. 147/133 RCS P/T Limits 3.4.11 I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME 1 4.C. ---------NOTE---------
Required Action C.2 shall be completed if this Condition is entered. I 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 LaSalle I and 2 3.4.11 -2 Amendment No. 147/133 RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 -NOTE Only required to be performed during RCS heat up and cool down operations, and RCS inservice leak and hydrostatic testing. Verify: a. RCS pressure and RCS temperature are within the applicable limits specified in Figures 3.4.11-1, 3.4.11 2, 3.4.11 3 for Unit 1 up to 32 EFPY, and Figures 3.4.11-4, 3.4.11 5, and 3.4.11-6 for Unit 2 up to 32 EFPY; b. RCS heatup and cool down rates are 100&deg;F in any 1 hour period; and c. RCS temperature change during system leakage and hydrostatic testing is 20&deg;F in anyone hour period when the RCS pressure and RCS temperature are not within the limits of Figure 3.4.11-2 for Unit 1 up to 32 EFPY and Figure 3.4.11 5 for Unit 2 up to 32 EFPY. In accordance with the Surveillance Frequency Control Program SR 3.4.11.2 Verify RCS pressure and ReS temperature are within the criticality limits specified in Figure 3.4.11-3 for Unit 1 up to 32 EFPY and Figure 3.4.11-6 for Unit 2 up to 32 EFPY. Once within 15 minutes prior to control rod withdrawal for the purpose of achieving criticality (continued)
LaSalle 1 and 2 3.4.11-3 Amendment No. 201/188 RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.11.3 ----NOTE-Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup. Verify the difference between the bottom head coolant temperature and the reactor pressure vessel (RPV) coolant temperature is::; 145&deg;F. Once withi n 15 minutes prior to each startup of a recirculation pump SR 3.4.11.4 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 ::; 50&deg;F. Once within 15 minutes prior to each startup of a SR 3.4.11.5 ------------Only required to be performed when tensioning the reactor vessel head bolting studs. Verify reactor vessel flange and head flange temperatures are 72&deg;F for Unit 1 and 86&deg;F for Unit 2. recirculation pump In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.4.11-4 Amendment No. 200 I 187 RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.6 Not required to be performed until 30 minutes after RCS temperature 77&deg;F for Unit 1 and 91&deg;F for Unit 2 in MODE 4. Verify reactor vessel flange and head flange temperatures are 72&deg;F for Unit 1 and 86&deg;F for Unit 2. In accordance with the Surveillance Frequency Control Program SR 3.4.11.7 ------NOTE--Not required to be performed until 12 hours after RCS temperature 92&deg;F for Unit 1 and 106&deg;F for Unit 2 in MODE 4. Verify reactor vessel flange and head flange temperatures are 72&deg;F for Unit 1 and 86&deg;F for Unit 2. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.11 5 Amendment No. 200 / 187 1400 1300 1200 1100 Ci 1000 c c( w J: 900 D. 0 1-...J w 800 Ill Ill w > a: 700 0 1-0 c( w 600 a: 1-i 500 ::::i w a: ::> 400 Ill Ill w a: D. 300 200 100 0 -----------
-+----
' ' ' ' ' ' ' ' ' -------. ' ' ' ' ' ' ' ' ' I
----,/----' ' ' ' -----------+-**-BOTTOM HEAD 68'F ' ' ' ' ' ' ' ' .. ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' '
J 1/ ---r I I i 1/ i I I / --------' ---------I ' RCS P/T Limits 3.4.11 INITIAL RT NDT VALUES ARE -30'F FOR BEL TUNE, 42'F FOR UPPER VESSEL, AND 47"F FOR BOTTOM HEAD BEL TUNE CURVES ADJUSTED AS SHOWN: EFPY SHIFT ('F) 32 146 HEATUP/COOLDOWN RATE OF COOLANT 20'F/HR 1---------*--I-0 ' ' ' I ' I ' ' ' ' 312 PSIG
-** ----------
FLANGE REGION 1--" .......--72'F ,....... I I 25 50 75 100 125 150 175 200 225 MINIMUM REACTOR VESSEL METAL TEMPERATURE
('F) Figure 3.4.11-1 (Page 1 of 1) Unit 1 --UPPER VESSEL AND BEL TUNE LIMITS -------BOTTOM HEAD CURVE -----------------
-.. P-T Curves for Hydrostatic or Leak Testing up to 32 EFPY i LaSalle 1 and 2 3.4.11-6 Amendment No. 210/188 1400 I 1300 ----'---_____ , -' ' ' ' ' ' ' ' ' ' ' ' ' RCS P/T Limits 3.4 .11 1200 t----1-------i---____ j_ INITIAL RTNDT VALUES ARE 1100 Oi ! 1000 c L5 :I: 900 a.. 0 1-...J w 800 U) U) w t-----t-----t---+---I --:-i I ! o I I I i -=::__[!_-
-3o*F FOR BEL TUNE, 42*F FOR UPPER VESSEL, AND 47"F FOR BOTTOM HEAD BEL TUNE CURVES ADJUSTED AS SHOWN: : I EFPY SHIFT (&deg;F) f---_____ ---1----___ j ----IJ+---+-----I L __ 3_2 __ 1_4_6 __ ...J > a:: 0 1-700 I l I '/ v --() L5 a:: 600 1-i 500 :::i w a:: ::l U) U) w a:: a.. 400 300 200 100 0 0 1/ 1---------,/j -------f-,/ I /I I L_L_ ] I ! --_____ ,_ -------BOTIOM ! HEAD f-:_ _ I --* :f !
* ' ' V REGION t--+--l-It-n*F !_ : It L____.,.______J
! ! !IY I : I 25 50 75 100 125 150 175 200 225 MINIMUM REACTOR VESSEL METAL TEMPERATURE
(&deg;F) Figure 3.4.11-2 (Page 1 of 1) Unit 1 HEATUP/COOLDOWN RATE OF COOLANT .:: 100.F/HR --UPPER VESSEL AND BEL TUNE LIMITS -------BOTTOM HEAD CURVE P-T Curves for Heatup by Non-Nuclear Means, (Core Not Critical)
Cool down Following a Nuclear Shutdown and Low Power Physics Testing up to 32 EFPY LaSalle 1 and 2 3.4.11-7 Amendment No. 210/188 1400 1300 1200 1100 -.!21 ; 1000 0 ca: w ::t 900 0.. 0 1-...J w 800 If) If) w > a: 700 0 1-0 ca: w 600 a: 1-i 500 :J w a: :::1 400 If) If) w a: 0.. 300 200 100 0 ------------! ' I i I I I ' ! I ! I ! i I i I I I I ! I J i 1-4--------------------------i ----------------------I ------I ! ' i,.--l312 PSIGI I I / ! I Minimum Vessel ! Temperature 72'F I I I I I ! I ' f----! RCS P/T Limits 3. 4.11 INITIAL RT NOT VALUES ARE -30oF FOR BEL TUNE, 42oF FOR UPPER VESSEL, AND 47"F FOR BOTTOM HEAD BEL TUNE CURVE ADJUSTED AS SHOWN: EFPY SHIFT (&deg;F) 32 146 HEATUP/COOLDOWN RATE OF COOLANT _:: 100&deg;F/HR -BEL TUNE AND BEL TUNE LIMITS 0 25 50 75 100 125 150 175 200 225 250 MINIMUM REACTOR VESSEL METAL TEMPERATURE
("F) Figure 3.4.11-3 (Page 1 of 1) Unit 1 P-T Curves for Operation with a Core Critical other than Low Power Physics Testing up to 32 EFPY LaSalle 1 and 2 3.4.11-8 Amendment No. 210/188 RCS PIT Limits 3.4.11 '1400 1300 1200 . J . I. I i : /. . /,. . J . , I.
* BOTTOM HEAD 6soF **** i *
** : FLANGE V REGION 86'F ,&#xa5; INITIAL RTndt VALUES _6&deg;F FOR LPCI 40'F FOR UPPER '1100 t>>';
FOR BOTTOM HEAD C 1000 Note: The LPCI Nozzle is the << w limiting material for the :r:: beltline region, a. 900 0 .... ...I W en 800 en w > a:: 0 700 .... 0 BEL TUNE CURVES i2i ADJUSTED AS SHOWN: a:: 600 EFPY SHIFT ("F) 2: 32 58.... :E 500::::i w a:: HEATUP/COOLDOWN
:::> en 400 RATE OF COOLANT en w .:: 20'FlHR a:: a. 300 -UPPER VESSEL AND BEL TUNE LIMITS ***... BOTTOM HEAD 200 100 CURVE o o 25 50 75 100 '125 150 175 200 MINIMUM REACTOR VESSEL METAL TEMPERATURE (OF) Figure 3.4.11 4 (Page 1 of 1) Unit 2 P T Curves for Hydrostatic or Leak Testing up to 32 EFPY LaSalle 1 and 2 3.4.11-9 Amendment No. 201/188 1400 1300 1200 1100 --. t:D l a 1000 << LU J: c.. 900 0 ...J LU (/) 800 (/) LU > a::: 0 700 l-t) << LU a::: 600 i 500:J LU a::: => (/) 400 (/) LU a::: c.. 300 200 100 o o I . I. . . . . . , . .. . . . *** . . . . . BOTTOM HEAD . S8<F // If' FLANGE /' REGION / 86 Q F 25 50 75 100 125 150 175 200 MINIMUM REACTOR VESSEL METAL TEMPERATURE
("F) Figure 3.4.11 5 (Page 1 of 1) Unit 2 Res PIT Limits 3.4.11 INITIAL RTndt -6&deg;F FOR LPCI 40&deg;F FOR 58.6"F FOR Note: The LPC I Nozzle the limiting material for beltline BELTLINE CURVES ADJUSTED AS SHOWN: EFPY SHIFT eF) 32 58 HEATUP/COOLDOWN RATE OF COOLANT ::.. 100*F/HR -UPPER VESSEL AND BEL TUNE LIMITS BOTTOM HEAD CURVE P T Curves for Heatup by Non-Nuclear Means. Cool down Following a Nuclear Shutdown and Low Power Physics Testing up to 32 EFPY LaSalle 1 and 3.4.11-10 Amendment No. 201/188 RCS PIT Limits 3.4.11 1400 1300 1200 1100 Ci Ui 1000 .:( w ::r: Q. 900 0 ...I W en 800 en w > It:: 0 700 0 .:( w It:: 600 :il 500::i w It:: ::l en 400 en w Ix: Q. 300 200 100 0 I 1 I I I 1 1 I I 1312 PSIGI ,....r-I 1 V J 1 /.-: i / Minimum Criticality r:: _ Temperature 86'F 1 I INITIAL RTndt VALUES ARE _6 c F FOR LPCI NOZZLE, 40&deg;F FOR UPPER VESSEL, AND 49&deg;F FOR BOnOM HEAD Note: The LPCI Nozzle is the limiting material for the beltline region. BELTLINE CURVE ADJUSTED AS SHOWN: EFPY SHIFT rF) 32 58 HEA TUP/COOLDOWN RATE OF COOLANT .::: 100"F/HR -BELTLINE AND NON-BELTLINE LIMITS o 25 50 75 100 125 150 175 200 225 250 MINIMUM REACTOR VESSEL METAL TEMPERATURE (OF) Figure 3.4.11-6 (Page 1 of Unit poT Curves for Operation with a Core other than Low Power Physics Testing up to 32 LaSalle 1 and 2 3.4.11-11 Amendment No. 201/188 Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome LCO 3.4.12 The reactor steam dome pressure shall be 1020 APPLICABILITY:
MODES 1 and 2. ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome pressure not within 1 i mit . 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 SR 3.4.12.1 Verify reactor steam dome pressure is 1020 psig.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.12 1 Amendment No .200 I 187 ECCS-Operating
: 3. 5 .1 3.5 EMERGENCY CORE COOLING SYSTEMS CECCS) AND REACTOR CORE ISOLATION COOLING CRCIC) SYSTEM 3.5.1 ECCS-Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System CADS) function of six safety/relief valves shall be OPERABLE.
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 A. One low pressure ECCS injection/spray subsystem inoperable.
LaSalle 1 and 2 A .1 REQUIRED ACTION COMPLETION TIME Restore low pressure 7 days ECCS injection/spray subsystem to OPERABLE status. (continued) 3.5.1-1 Amendment Nos. 217/203 3.5.1 ECCS-Operating ACTIONS CONDITION B. High Pressure Core Spray (HPCS) System inoperable.
B.1 REQU I RED ACTI ON Verify by administrative means RCIC System is OPERABLE when RCIC is required to be OPERABLE.
COMPLETION TIME Immediately B.2 Restore HPCS System to OPERABLE status. 14 days C. Two low pressure ECCS injection/spray subsystems inoperable.
C.1 Restore one low pressure 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 Be in MODE 3. 12 hours E. One required ADS valve inoperable.
E.1 Restore required ADS valve to OPERABLE status. 14 days F. Requi red Acti on and associated Completion Time of Condition E not met. F.1 Be in MODE 3. 12 hours (contlnued)
LaSalle 1 and 2 3.5.1 2 Amendment No 196/183 3.5.1 ECCS-Operating ACTIONS CONDITION REQUI RED ACTION COMPLETION TIME G. Two or more required ADS valves inoperable. .Q.R ADS accumulator backup compressed gas system inoperable.
G.I AND G.2 Be in MODE 3. Reduce reactor steam dome pressure to ::; 150 psig. 12 hours 36 hours H. HPCS and one or more low pressure ECCS injection/spray subsystems inoperable.
OR Three or more ECCS injection/spray subsystems inoperable . .Q.R One or more ECCS injection/spray subsystems and one or more required ADS valves inoperable.
H.I Enter LCO 3.0.3. Immediately LaSall eland 2 3.5.1-3 Amendment No 196/183 SURVEILLANCE REQUIREMENTS SR 3.5.1.1 SR 3.5.1.2 SR 3.5.1.3 SR 3.5.1.4 SURVEILLANCE Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. -------------------NOTE--------------------Not required to be met for system vent flow paths opened under administrative control. 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.
Verify ADS accumulator supply header pressure 150 psig. Verify ADS accumulator backup compressed gas system bottle pressure is 500 psig. Verify ADS accumulator reserve bottle pressure 1100 psig. ECCS-Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.5.1-4 Amendment Nos. 214/200 I SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.1.5 SR 3.5.1.6 SR 3.5.1.7 SR 3.5.1.8 SURVEILLANCE Verify each ECCS pump develops the specified flow rate against the specified test line pressure.
TEST LINE SYSTEM FLOW RATE PRESSURE LPCS 2 6350 gpm 2 290 psig LPCI 2 7200 gpm 2 130 psig HPCS (Unit 1) 2 6250 gpm 2 370 psig HPCS (Unit 2) 2 6200 gpm 2 330 psig -------------------
NOTE--------------------
Vessel injection/spray may be excluded.
Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal. -------------------
NOTE--------------------
Valve actuation may be excluded.
Verify the ADS actuates on an actual or simulated automatic initiation signal. -------------------
NOTE--------------------
Valve actuation may be excluded.
Verify each required ADS valve actuator strokes when manually actuated.
ECCS-Operating 3.5.1 FREQUENCY In accordance with the Inservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.5.1-5 Amendment Nos. 214/200 ECCS -Shutdown 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 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 spent and water level > 22 ft pressure vessel flange.fuel storage pool gates removed over the top of the reactor ACTIONS .CONDITION REQUIRED ACTION COMPLETION TIME A. One required ECCS A.1 Restore required ECCS 4 hours injection/spray injection/spray subsystem inoperable.
subsystem to OPERABLE status.B. Required Action and B.1 Initiate action to Immediately associated Completion suspend operations Time of Condition A with a potential for not met. draining the reactor vessel (OPDRVs).(continued)
LaSalle I and 2 3.5.2-1 Amendment No. 147/133 ECCS- Shutdown 3.5.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Two required ECCS C.1 Initiate action to Immediately injection/spray suspend OPDRVs.subsystems inoperable.
AND C.2 Restore one required 4 hours ECCS injection/spray subsystem to OPERABLE status.D. Required Action C.2 D.1 Initiate action to Immediately and associated restore secondary Completion Time not containment to met. OPERABLE status.AND D.2 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.AND D.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.LaSalle I and 2 3.5.2- 2 Amendment No. 147/133 ECCS-Shutdown
: 3. 5. 2 SURVEILLANCE REQUIREMENTS SR 3.5.2.1 SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 LaSalle 1 and 2 SURVEILLANCE Verify, for each required low pressure ECCS injection/spray subsystem, the suppression pool water level is 2 -12 ft 7 in. Verify, for the required High Pressure Core Spray CHPCS) System, the suppression pool water level is 2 -12 ft 7 in. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Verify, for each required ECCS injection/
In accordance spray subsystem, locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. -------------------NOTE--------------------
Not required to be met for system vent flow paths opened under administrative control. 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.
Verify each required ECCS pump develops the specified flow rate against the specified test line pressure.
TEST LINE SYSTEM FLOW RATE PRESSURE LPCS 2 6350 gpm 2 290 psig LPCI 2 7200 gpm 2 130 psig HPCS (Unit 1) 2 6250 gpm 2 370 psig HPCS (Unit 2) 2 6200 gpm 2 330 psig Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Inservice Testing Program (continued) 3.5.2-3 Amendment Nos. 214/200 ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS 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.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.5.2 4 Amendment No. 200/ 187 RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 APPLICABILITY:
The RCIC System shall be OPERABLE.MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.ACTIONS-,-,,-,--..
-----NOTE------------------''-''
LCO 3.0.4.b is not applicable to RCIC.CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System A.1 Verify by Immediately inoperable.
administrative means High Pressure Core Spray System is OPERABLE.A.2 Restore RCIC System 14 days to OPERABLE status.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. ALD B.2 Reduce reactor steam 36 hours dome pressure to S 150 psig.LaSalle I and 2 3.5.3-1 Amendment No. /171/157 4 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 SURVEILLANCE Verify the RCIC System locations susceptible to gas accumulation are sufficiently filled with water. -------------------NOTE--------------------
Not required to be met for system vent flow paths opened under administrative control. 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. -------------------
NOTE--------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure 1020 psig and 2 920 psig, the RCIC pump can develop a flow rate 2 600 gpm against a system head corresponding to reactor pressure. -------------------NOTE--------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor 165 psig, the RCIC pump can develop a flow rate 2 600 gpm against a system head corresponding to reactor pressure.
RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.5.3-2 Amendment Nos. 214/200 RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SR Vessel Verify actual signal. NOTE --injection may be excluded.
the RCIC System actuates on an or simulated automatic initiation In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.5.3-3 Amendment No. 200 / 187 Primary Containment 3.6.1.1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment LCO 3.6.1.1 APPLICABILITY:
Primary containment shall be OPERABLE.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.I Restore primary 1 hour inoperable, containment to OPERABLE status.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met.I LaSalle I and 2 3.6.1.1-1 Amendment No.184 /71 Primarv Containment 3.6.1.1 SURVEILLANCE REOUIREMENTS
_SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and In accordance leakage rate testing except for primary with the containment air lock testing, in Primary accordance with the Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.1.2 Verify primary containment structural In accordance integrity in accordance with the with the Inservice Inspection Program for Post Inservice Tensioning Tendons. Inspection Program for Post Tensioning Tendons (continued)
LaSalle 1 and 2 3.6.1.1-2 Amendment No. 149, 135 IlOV 0 7 2001 Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SR 3.6.1.1.3 Verify drywell-to-suppression chamber bypass leakage is 10% of the acceptable A/Jk design val ue of 0.030 ft2 at an initial differential pressure of 1.5 psid. FR In accordance with the Surveillance Frequency Control Program 48 months following a test with bypass leakage greater than the bypass leakage limit 24 months following 2 consecutive tests with bypass 1 eakage grater than the bypass 1 eakage limit until 2 consecutive tests are less than or equal to the bypass leakage limit (continued)
LaSalle 1 and 2 3.6.1.1-3 Amendment No. 200 / 187 Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SR 3.6.1.1.4 SURVEILLANCE Performance of SR 3.6.1.1.3 satisfies this surveillance.
Verify individual drywell to suppression chamber vacuum relief valve bypass leakage is ::: 1.2% of the acceptable A/Jk design value of 0.030 ft2 at an initial differential pressure of 1.5 psid. FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.6.1.1.5 Performance of SR 3.6.1.1.3 satisfies this surveillance.
Verify total drywell-to suppression chamber vacuum relief valve bypass leakage is ::: 3.0% of the acceptable A IJk des i gn value of 0.030 ft2 at an initial differential pressure of 1.5 psid. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.1.1-4 Amendment No. 200 I 187 
.Primary Containment Air Lock 3.6.1.2 3.6 CONTAINMENT SYSTEMS 3.6.1.2 Primary Containment Air Lock LCO 3.6.1.2 APPLICABILITY:
The primary containment air lock shall be OPERABLE.MODES 1. 2. and 3.ACTIONS--- ---------------
NOTES------------------------------------
: 1. Entry and exit is permissible to perform repairs of the air lock components.
: 2. 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 REHUIRED ACTION COMPLETION TIME A. One primary ------------
NOTES------------
containment air lock 1. Required Actions A.1, door inoperable.
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.(continued)
LaSalle 1 and 2 3.6.1.2-1 Amendment No. 147/133 Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.1 Verify the OPERABLE 1 hour door is closed.AND A.2 Lock the OPERABLE 24 hours door closed.AND A.3 ---- NOTE---------
Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.Verify the OPERABLE Once per 31 days door is locked closed.B. Primary containment
------------
NOTES------------
air lock interlock
: 1. Required Actions B.J.mechanism inoperable.
B.2. and B.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.2. Entry into and exit from primary containment is permissible under the control of a dedicated individual.(continued)
LaSalle I and 2 3.6.1.2- 2 Amendment No. 147/133 Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)
B.1 Verify an OPERABLE 1 hour door is closed.AND B.2 Lock an OPERABLE door 24 hours closed.AND B.3 --------NOTE---------
Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.Verify an OPERABLE Once per 31 days door is locked closed.C. Primary containment C.1 Initiate action to Immediately air lock inoperable evaluate primary for reasons other than containment overall Condition A or B. leakage rate per LCO 3.6.1.1. using current air lock test results.AND C.2 Verify a door is 1 hour closed.AND (continued)
LaS.alle 1 and 2 3.6.1.2-3 Amendment No. 147/133 Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)
C.3 Restore air lock to OPERABLE status. 24 hours D. Required Action and associated Completion Time not met. D.1 AND D.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours SURVEILLANCE SURVEILLANCE 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 1 ea kage 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 In accordance with the with the Primary Containment Leakage Rate Testing Program. SR 3.6.1.2.2 Verify only one door in the primary containment air lock can be opened at a time. Primary Containment Leakage Rate Testing Program In accordance with the Surveillance Frequency Control Program LaSall e 1 and 2 3.6.1.2-4 Amendment NO.200 / 187 PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)LCO 3.6.1.3 APPLICABILITY:
Each PCIV shall be OPERABLE.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 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.CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE---------
A.1 Isolate the affected 4 hours except Only applicable to penetration flow path for main steam penetration flow paths by use of at least line with two or more one closed and PCIVs. de-activated AND automatic valve.closed manual valve, 8 hours for main One or more blind flange, or steam line penetration flow paths check valve with flow with one PCIV through the valve inoperable for reasons secured.other than Condition D. AND (continued)
La~alle 1 and 2 3.6.1.3-1 Amendment No. 147/133 PCIVs 3.6.1.3 ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. (continued)
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 AND Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4. if not performed within the previous 92 days, for isolation devices inside primary containment (continued)
LaSalle 1 and 2 3.6.1.3-2 Amendment No. 147/133 PCIVs 3.6.1.3 ACTIONS'S.- CONDITION REQUIRED ACTION COMPLETION TIME B. ---------NOTE------
B.1 Isolate the affected 1 hour Only applicable to penetration flow path penetration flow paths by use of at least with two or more one closed and PCIVs. de-activated automatic valve, closed manual valve.One or more or blind flange.penetration flow paths with two or more PCIVs inoperable for reasons other than Condition D.C. ---------NOTE--------
C.1 Isolate the affected 4 hours except Only applicable to penetration flow path for excess flow penetration flow paths by use of at least check valves with only one PCIV. one closed and (EFCVs) and; de-activated penetrations automatic valve, with a closed One or more closed manual valve, system penetration flow paths or blind flange.with one PCIV AND inoperable for reasons other than 72 hours for Condition D. EFCVs and penetrations with a closed system AND (continued)
LaSalle 1 and 2 3.6.1 .3-3 Amendment No. 147/133 PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)
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 administrative means.Verify the affected Once per 31 days penetration flow path is isolated.D. One or more D.1 Restore leakage rate 4 hours for penetration flow paths to within limit. hydrostatically with MSIV leakage rate tested line or hydrostatically leakage not on a tested line leakage closed system rate not within limit.AND 8 hours for MSIV leakage AND 72 hours for hydrostatically tested line leakage on a closed system (continued).LaSalle I and 2 3.6.1.3-4 Amendment No. 147/133 PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, AND B, C, or D not met in MODE 1. 2, or 3. E.2 Be in MODE 4. 36 hours F. Required Action and F.1 Initiate action to Immediately associated Completion suspend operations Time of Condition A. with a potential for B, C, or D not met for draining the reactor PCIV(s) required to be vessel (OPDRVs).OPERABLE during MODE 4 or 5. OR F.2 Initiate action to Immediately restore valve(s) to OPERABLE status.LaSalle 1 and 2 3.6.1.3-5 Amendment No. 147/133 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.1.3.1 ------------------
NOTE ---------------Not required to be met when the 8 inch and 26 inch primary containment purge valves are open for inerting, inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open, provided the drywell purge valves and suppression chamber purge valves are not open simultaneously.
Verify each 8 inch and 26 inch primary containment purge valve is closed. In accordance with the Surveillance Frequency Control Program SR 3.6.1.3.2 ------------------
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 and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.6.1.3-6 Amendment No.200/187 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.3 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 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 primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days SR 3.6.1.3.4 Verify continuity of the traversing incore probe (TIP) shear isolation valve explosive charge. In accordance with the Surveillance Frequency Control Program 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 (continued)
LaSalle 1 and 2 3.6.1.3-7 Amendment No. 200/187 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.6 Verify the isolation time of each MSIV is 3 seconds and 5 seconds. In accordance with the Inservice Testing Program SR 3.6.1.3.7 Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal. In accordance with the Surveillance Frequency Contro 1 Prog ram SR 3.6.1.3.8 Verify each reactor instrumentation line EFCV actuates to the isolation position on an actual or simulated instrument line break signal. In accordance with the Surveillance Frequency Control Program SR 3.6.1.3.9 Remove and test the explosive squib from each shear isolation valve of the TIP System. In accordance with the Surveillance Frequency Control Program SR 3.6.1.3.10 Verify leakage rate through anyone main steam line is 200 scfh and through all four main steam lines is 400 scfh when tested at 25.0 psig. In accordance with the Primary Containment Leakage Rate Testing Program SR 3.6.1.3.11 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 LaSalle 1 and 2 3.6.1.3-8 Amendment No. 200/187 Drywell and Suppression Chamber Pressure 3.6.1.4 3.6 SYSTEMS 3.6.1.4 and Suppression Chamber Pressure 3.6.1.4 Drywell and suppression chamber pressure shall be 0.5 psig and $ +0.75 psig. APPLICABI LITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell or suppression chamber pressure not within limits. A.l Restore drywell and suppression chamber pressure to within limits. 1 hour B. Required Action and associated Completion Time not met. B.l AND B.2 Be Be in in MODE MODE 3. 4. 12 36 hours hours SURVEILLANCE SURVEI SR 3.6.1.4.1 Verify drywell and suppression chamber pressure is within limits.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.6.1.4 1 Amendment NO*200 /187 Drywell Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Drywell Air LCO 3.6.1.5 Drywell average ai r temperature shall be s APPLICABI LITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION ON TIME A. Drywell average air temperature not within 1 i mi t. A.1 Restore drywell average air temperature to within 1 i mit. 8 hours B. Required Action and associated Completion Ti me not met. B.1 AND B.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours SURVEILLANCE SR 3.6.1.5.1 Verify drywell average air temperature is within limit.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.1.5-1 Amendment No. 200 / 187 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers LCO 3.6.1.6 APPLICABILITY:
Each suppression chamber-to-drywell vacuum breaker shall be OPERABLE.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One suppression A.1 Restore the vacuum 72 hours chamber-to-drywell breaker to OPERABLE vacuum breaker status.inoperable for opening.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not met.C. One suppression C.1 Close both manual 4 hours chamber-to-drywell isolation valves in vacuum breaker not the affected line.closed.AND C.2 Restore the vacuum 72 hours breaker to OPERABLE status.D. Required Action and D.1 Be in MODE 3. 12 hours associated Completion Time of Condition C ^ua not met.D.2 Be in MODE 4. 36 hours (continued)
LaSalle 1 and 2 3.6. 1.6-1 Amendment No. 18-4/171 Suppression Chamber to Drywell Vacuum Breakers 3.6.1.6 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME E. Two or more suppression chamber-to-drywell vacuum breakers -inoperable.
E.1 Enter LCO 3.0.3. Immediately 3.6.1.6.1 NOTES -----------Not required to be met for vacuum breakers that are open during Surveillances. Not required to be met for vacuum breakers open when performing their intended function.
Verify each vacuum breaker is closed.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.6.1.6-2 Amendment No. 200 / 187 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 SURVEILLANCE REQUIREMENTS SR 3.6.1. 6 . 2 SURVEILLANCE Perform a functional breaker. test of each vacuum FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.6.1.6.3 Verify the opening setpoint of each vacuum breaker is 0.5 psid. Within 12 hours after any discharge of steam to the suppression chamber from the safety/relief valves In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.1.6-3 Amendment No. 200/ 187 Suppression Pool Average Temperature 3.6.2.1 3.6 CONTAINMENT SYSTEMS 3.6.2.1 Suppression Pool Average Temperature LCO 3.6.2.1 Suppression pool average temperature shall be: a. < 105 0 F with THERMAL POWER > 1% RTP; and b. < 110'F with THERMAL POWER < 1% RTP.APPLICABILITY:
MODES 1, 2. and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool A.1 Suspend all testing Immediately average temperature that adds heat to the> 105 0 F but < 110 0 F. suppression pool.AND AND THERMAL POWER > 1% A.2 Verify suppression Once per hour RTP. pool average temperature
< 110 0 F.AND A.3 Restore suppression 24 hours pool average temperature to< 105 0 F.B. Required Action and B.1 Reduce THERMAL POWER 12 hours associated Completion to < 1% RTP.Time of Condition A not met.(continued)
LaSalle I and 2 3.6.2.1-1 Amendment No. 147/133 Suppression Average Temperature 3.6.2.1 ACTIONS REQUIRED ACTION ON TIME e C. Suppression pool C.1 Place the reactor Immediately average temperature mode switch in the > 110&deg;F but 120&deg;F. shutdown position.
AND C.2 Verify suppression Once per pool average 30 minutes temperature 120&deg;F. Mill C.3 Be in MODE 4. 36 hours Suppression pool D.1 Depressurize the 12 hours average temperature reactor vessel to > 120&deg;F. < 200 psig. AND D.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR Verify suppression pool average temperature is within the applicable limits.
In accordance with the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool LaSalle 1 and 3.6.2. 2 Amendment No. 200 I 187 Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool s +3 inches. water level shall be;:::: 4.5 inches and APPLICABILITY:
MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water 1 eve 1 not within 1 i mits . A.1 Restore suppression pool water 1 evel to withi n 1 i mits. 2 hours B. Required Action and associated Completion Ti me not met. B.1 AN..D. B.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours SURVEILLANCE SR 3.6.2.2.1 Verify suppression pool water level is within limits.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.2.2-1 Amendment No. 200 I 187 RHR Suppression Pool Cool i ng 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 APPLICABILITY:
Two RHR suppression pool cooling subsystems shall be OPERABLE.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR 7 days pool cooling subsystem suppression pool inoperable, cooling subsystem to OPERABLE status.B. Required Action and B. Be in MODE 3. 12 hours associated Completion Time of Condition A not met.C. Two RHR suppression C.1 Restore one RHR 8 hours pool cooling suppression pool subsystems inoperable, cooling subsystem to OPERABLE status.D. Required Action and D.1 Be in MODE 3. 12 hours associated Completion Time of Condition C AND not met.D.2 Be in MODE 4. 36 hours LaSalle I and 2 3.6.2.3-1 Amendment No. 184/171 RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SR 3.6.2.3.1 SR 3.6.2.3.2 SR 3.6.2.3.3 LaSalle 1 and 2 SURVEILLANCE Verify each RHR suppression pool cooling subsystem manual and power operated 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.
Verify each required RHR pump develops a flow rate 7200 gpm through the associated heat exchanger while operating in the suppression pool cooling mode. Verify RHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Inservice Testing Program In accordance with the Surveillance Frequency Control Program 3.6.2.3-2 Amendment Nos. 214/200 RHR Suppression Pool Spray 3.6.2.4 3.6 CONTAINMENT SYSTEMS 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray LCO 3.6.2.4 Two RHR suppression pool spray subsystems shall be OPERABLE.APPLICABILITY:
MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR 7 days pool spray subsystem suppression pool inoperable, spray subsystem to OPERABLE status.B. Two RHR suppression B.1 Restore one RHR 8 hours pool spray subsystems suppression pool inoperable, spray subsystem to OPERABLE status.C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time not met.LaSalle I and 2 3.6.2.4-1 Amendment No. 184/171 RHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SR 3.6.2.4.1 SR 3.6.2.4.2 SR 3.6.2.4.3 LaSalle 1 and 2 SURVEILLANCE Verify each RHR suppression pool spray subsystem manual and power operated 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.
Verify each required RHR pump develops a flow 450 gpm through the spray sparger while operating in the suppression pool spray mode. Verify RHR suppression pool spray subsystem locations susceptible to gas accumulation are sufficiently filled with water. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Inservice Testing Program In accordance with the Surveillance Frequency Control Program 3.6.2.4-2 Amendment Nos. 214/200 3.6.3. 1 3.6 CONTAINMENT SYSTEMS 3.6.3.1 (Deleted)
I LaSalle I and 2 3.6.3 .1-1 Amendment No. 172/158 Primary Containment Oxygen Concentration 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment Oxygen Concentration LCO 3.6.3.2 The primary containment oxygen concentration shall be < 4.0 volume percent. APPLICABI LITY: MODE 1 during the time period: a. From 24 hours sta rtup, to after THERMAL POWER is > 15% RTP following
: b. 24 hours prior to prior the to next reducing THERMAL scheduled reactor P OWER to < shutdown.
15% RTP CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment oxygen concentration not withi n 1 i mit. A .1 Restore oxygen concentration to within 1 i mit. 24 hours B. Required Action and associated Completion Time not met. B.1 Reduce THERMAL to 15% RTP. POWER 8 hours SURVEILLANCE SURVEI SR 3.6.3.2.1 Verify primary containment oxygen concentration is within limits.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.3.2-1 Amendment No.200 / 187 Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.APPLICABILITY:
MODES 1, 2, and 3, During movement of irradiated fuel secondary containment, During CORE ALTERATIONS, During operations with a potential vessel (OPDRVs).assemblies in the for draining the reactor ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable in MODE 1, containment to 2, or 3. OPERABLE status.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not met.(continued)
LaSalle 1 and 2 3.6.4.1-1 Amendment No. 184 471 Secondary Containment 3.6.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment C.1 --------NOTE---------
inoperable during LCO 3.0.3 is not movement of irradiated applicable.
fuel assemblies in the secondary containment, during CORE Suspend movement of Immediately ALTERATIONS, or during irradiated fuel OPDRVs. assemblies in the secondary containment.
AND C.2 Suspend CORE Immediately ALTERATIONS.
AND C.3 Initiate action to Immediately suspend OPDRVs.LaSalle 1 and 2 3.6.4.1 -2 Amendment No. 147/133 Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is 0.25 inch of vacuum water gauge. In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.2 Verify one secondary containment access door in each access opening is closed. In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.3 Verify the secondary containment can be drawn down to 0.25 inch of vacuum water gauge in 900 seconds using one standby gas treatment (SGT) subsystem.
In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.4 Verify the secondary containment can be maintained 0.25 inch of vacuum water gauge for 1 hour using one SGT subsystem at a flow rate 4400 cfm. In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.5 Verify all secondary containment equipment hatches are closed and sealed. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.4.1 3 Amendment No. 200/187 SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)LCO 3.6.4.2 APPLICABILITY:
Each SCIV shall be OPERABLE.MODES 1. 2. and 3.During movement of irradiated fuel assemblies in the secondary containment.
During CORE ALTERATIONS.
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 A.1 Isolate the affected 8 hours penetration flow paths penetration flow path with one SCIV by use of at least inoperable.
one closed and de-activated automatic valve, closed manual valve, or blind flange.AND (continued)
LaS.alle I and 2 3.6.4.2 -1 Amendment No. 147/133 SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
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 controls.Verify the affected Once per 31 days penetration flow path is isolated.B. ---------NOTE---------
B.1 Isolate the affected 4 hours Only applicable to penetration flow path penetration flow paths by use of at least with two isolation one closed and valves. de-activated automatic valve.closed manual valve, One or more or blind flange.penetration flow paths with two SCIVs inoperable.
C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A AND or B not met in MODE 1. 2, or 3. C.2 Be in MODE 4. 36 hours (continued)
LaSalle 1 and 2 3.6.4.2-2 Amendment No. 147/133 SCIVs 3.6.4.2~'j ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME D. Required Action and D.1 --------NOTE---------
associated Completion LCO 3.0.3 is not Time of Condition A applicable.
or B not met during movement of irradiated fuel assemblies in the Suspend movement of Immediately secondary containment, irradiated fuel during CORE assemblies in the ALTERATIONS, or during secondary OPDRVs. containment.
AND D.2 Suspend CORE Immediately ALTERATIONS.
AND D.3 Initiate action to Immediately suspend OPDRVs.LaSalle I and 2 3.6.4.2-3 Amendment No. 147/133 SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLMCE FREQUENCY SR 3.6.4.2.1
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls.
Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed or otherwise secured in position and is required to be closed during accident conditions is closed. In accordance with the Surveillance Frequency Control Program SR 3.6.4.2.2 Verify the isolation time of each power operated, automatic SCIV is within limits. 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. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.4.2 4 Amendment No .200 / 187 SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.APPLICABILITY:
MODES 1, 2, and 3, During movement of irradiated fuel secondary containment, During CORE ALTERATIONS, During operations with a potential vessel (OPDRVs).assemblies in the for draining the reactor ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days inoperable, to OPERABLE status.B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not met in MODE 1, 2, or 3.C. Required Action and ------------
NOTE -------------
associated Completion LCO 3.0.3 is not applicable.
Time of Condition A not met during movement of irradiated C.1 Place OPERABLE SGT Immediately fuel assemblies in the subsystem in secondary containment, operation.
during CORE ALTERATIONS, or during OR OPDRVs.(continued)
I LaSalle I and 2 3.6.4.3-1 Amendment No. 184/ 171 SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)
C.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.
AND C.2.2 Suspend CORE Immediately ALTERATIONS.
AND C.2.3 Initiate action to Immediately suspend OPDRVs.D. Two SGT subsystems D.1 Be in MODE 3 12 hours inoperable in MODE 1, 2, or 3.E. Two SGT subsystems E.1 ---------
NOTE ---------inoperable during LCO 3.0.3 is not movement of irradiated applicable.
fuel assemblies in the ---------------------
secondary containment, during CORE Suspend movement of Immediately ALTERATIONS, or during irradiated fuel OPDRVs. assemblies in the secondary containment.
AND (continued)
LaSalle I and 2 3. 6.4 .3-2 Amendment No.184 171 ACTIONS CONDITION REQUIRED ACTION E. (continued>
E.2 E.3 Suspend CORE ALTERATIONS.
Initiate action to suspend OPORVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.3.1 SR 3.6.4.3.2 SR 3.6.4.3.3 SURVEILLANCE Operate each SGT subsystem for 15 continuous minutes with heaters operating.
Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program {VFTP). Verify each SGT subsystem actuates on an actual or s1mulated 1nitiation signal. SGT System 3.6.4.3 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance With the VFTP In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.4.3-3 Amendment No. 2081195 RHRSW System 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Residual Heat Removal Service Water (RHRSW) System LCO 3.7.1 Two RHRSW subsystems shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3. ACTI ONS CONDITION REQU I RED ACTI ON
 
A. One RHRSW subsystem inoperable.
A.l ------NOTE -----Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown," for RHR shutdown cooling subsystem made inoperable by RHRSW System. Restore RHRSW subsystem to OPERABLE status. 7 days (continued)
LaSalle 1 and 2 3.7.1-1 Amendment No. 194/181 RHRSW System 3.7.1 ACTIONS B. CONDITION Required Action and associated Completion Time of Condition A not met. B.1 REQUIRED ACTION Be in MODE 3. COMPLETION 12 hours TIME C. Both RHRSW subsystems inoperable.
C.1
--Enter applicable Conditions and Required Actions of LCO 3.4.9 for RHR shutdown cooling subsystems made inoperable by RHRSW System. -----
Restore one RHRSW subsystem to OPERABLE status. 8 hours D. Required Action and associated Completion Time of Condition C not met. D .1 AND D.2 Be Be in MODE in MODE 3. 4. 12 36 hours hours SURVEILLANCE SR 3.7.1. Verify each RHRSW 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.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.7.1-2 Amendment No. 200 1 187 DGCW System 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Diesel Generator Cooling Water (DGCW) System LCO 3.7.2 The following DGCW subsystems shall be OPERABLE:
: a. Three DGCW subsystems; and b. The opposite unit Division 2 DGCW subsystem.
APPLI CABI LITY: MODES 1, 2, and 3. ACTIONS Separate Condition entry is allowed for each DGCW subsystem.
CONDITION REQU I RED ACTI ON COMPLETION TIME A. One or more DGCW subsystems inoperable.
A.l Declare supported component(s) inoperable.
Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.2.1 Verify each DGCW 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.
In accordance with the Surveillance Frequency Control Program SR 3.7.2.2 Verify each DGCW pump starts automatically on each required actual or simulated initiation signal. In accordance with the Survei 11 ance Frequency Control Program LaSall e 1 and 2 3.7.2-1 Amendment No. 200/ 187 3.7 PLANT SYSTEMS 3.7.3 Ultimate Heat Sink (UHS) UHS 3.7.3 LCO 3.7.3 The Core Standby Cooling System (CSCS) pond shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3. ACTIONS CONDITION A. CSCS pond inoperable due to sediment deposition or bottom elevation not within limit. B. Cooling water temperature supplied to the plant from the CSCS 10l&deg;F. C. Required Action and associated Completion Time of Condition A not met. CSCS pond inoperable for reasons other than Condition A. LaSalle land 2 A .1 B.l C.l C.2 REQUIRED ACTION Restore CSCS pond to OPERABLE status. Perform SR 3.7.3.1. Be in MODE 3. Be in MODE 4. COMPLETION TIME 90 days Once per hour 12 hours 36 hours 3.7.3-1 Amendment SURVEILLANCE REQUIREMENTS SR 3.7.3.1 SR 3.7 .3.2 SR 3.7.3.3 SURVEILLANCE Verify cooling water temperature supplied to the plant from the CSCS pond is within the limits of Figure 3.7.3-1. Verify sediment level is 1.5 ft in the intake flume and the CSCS pond. Verify CSCS pond bottom elevation is 686.5 ft. UHS 3.7.3 FREQUENCY In accordance with the Survei 11 ance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.7.3-2 Amendment No. 218/204 105.00 104. 50 *1----------1------
104.00 ;:;:: 103.50 OJ .... .;:; 103.00 "' .... OJ 0. E ;!l 102.50 102.00 101. 50 ! ! -*-1** Unacceptable Operation (102.44) * --------*---'----------*
--c--------*
(104.00) i -* ' (104.00) I (104.00) Acceptable Operation 1--(104.00) --i------101. 00 -'-' ----'------r-----+-----i-----'---------+----....!
UHS 3. 7. 3 (103.78) 00:00 03:00 06: 00 09:00 12:00 15:00 18:00 21:00 24:00 Time of Day Figure 3. 7.3-1 (page 1 of 1) Temperature of Cooling Water Supplied to the Plant from the CSCS Pond Versus Time of Day Requirements LaSalle 1 and 2 3.7.3-3 Amendment No. 218/204 CRAF System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Area Filtration (CRAF) System LCO 3.7.4 Two CRAF 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 irradiated fuel secondary containment, During CORE ALTERATIONS, During operations with a potential vessel (OPDRVs).assemblies in the for draining the reactor ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRAF subsystem A.1 Restore CRAF 7 days inoperable for reasons subsystem to OPERABLE other than Condition status.B.B. One or more CRAF B.1 Initiate action to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions.boundary in MODE 1, 2, or 3. AND B.2 Verify mitigating 24 hours actions ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.AND B.3 RestoreCRE--bound-a-ry--  -days-to OPERABLE status.(continued)
LaSalle I and 2 3.7.4-1 Amendment No186/171 CRAF System 3.7.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours Associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.D. Required Action and -------------
NOTE-----------
associated Completion LCO 3.0.3 is not applicable.
Time of Condition A not met during movement of irradiated 0.1 Place OPERABLE C'RAF Immediately fuel assemblies in the subsystem in secondary containment, pressurization mode.during CORE ALTERATIONS, or during OR OPDRVs.D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.
AND D.2.2 Suspend CORE Immediately ALTERATIONS.
AND D.2.3 Initiate action to Immediately suspend OPDRVs.E. Two CRAF subsystems E.1 Be in MODE 3. 12 hours inoperable in MODE 1, 2, or 3 for reasons other than Condition B.(continued)
I LaSalle I and 2 3. 7.4-2 Amendment No.1 8 6/1 7 3 I ACTIONS CONDIT ION REQUIRED ACTION CRAF System 3.7.4 COMPLETION T lME F. Two CRAF subsystems inoperable during ------------NOTE-------------LCO 3.0.3 is not applicable.
movement of irradiated fuel assemblies in the secondary containment, F.l during CORE ALTERATIONS, or during OPDRVs. One or more CRAF subsystems inoperable F.2 due to inoperable CRE boundary during movement of irradiated AMQ fuel assemblies in the secondary containment, F.3 during CORE ALTERATIONS, or during OPORVS. SURVEILLANCE REQUIREMENTS Suspend movement of irradiated fuel assemblies in the secondary containment.
Suspend CORE ALTERATIONS.
Initiate action to suspend OPDRVs. SURVEILLANCE SR 3.7.4.1 LaSalle 1 and 2 Operate each CRAF subsystem for 15 continuous minutes with the heaters operating.
3.7.4-3 Immediately Immediately Immediately FREQUENCY In accordance with the Survei 11 a nee Frequency Control Program {continued)
Amendment No.2f)B/195 SURVEILLANCE REQUIREMENTS SR 3.7.4.2 SR 3.7.4.3 SR 3.7.4.4 SR 3.7.4.5 SURVEILLANCE Manually initiate flow through the CRAF recirculation filters 15 minutes. Perform required CRAF filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each CRAF subsystem actuates on an actual or simulated initiation signal. Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program. CRAF System 3.7.4 FREQUENCY In accordance w1th the Surveillance Frequency Control Program In accordance with the VFTP In accordance wHh the Surveillance Frequency Control Program In accordance with the Control Room Envelope Habitability Program LaSalle 1 and 2 3.7.4-4 Amendment No. 208/195 Control Room Area Ventilation AC System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Control Room Area Ventilation Air Conditioning (AC) System LCO 3.7.5 Two. control room area ventilation AC s:ubsystems s-hall be OPERABLE.APPLICABILITY:
MODES 1, 2, and 3, During movement of irradi.ated fuel secondary containment, During CORE ALTERATIONS, During operations with a potential-vessel (OPDRVs).assemblies in the for draining the reactor ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room area A.1 Restore control room 30 days ventilation AC area ventilation AC subsystem inoperable, subsystem to OPERABLE status.B. Two control room area B.1 Verify control room Once per 4 ventilation AC area temperature hours subsystems inoperable.
< 90'F.AND B.2 Restore one control 72 hours room area ventilation AC subsystem to OPERABLE status.C. Required Action and C.1 Be in MODE 3. 12 hours Associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.(continued)
LaSalle 1 and 2 3.7.5-1 Amendment No. 188/175 Control Room Area Ventilation AC System 3.7.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and ------------
NOTE-----------
associated Completion LCO 3.0.3 is not applicable.
Time of Condition A not met during movement of irradiated D.1 Place OPERABLE Immediately fuel assemblies in the control room area secondary containment, ventilation AC during CORE subsystem in ALTERATIONS, or during operation.
OPDRVs.OR D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.
AND D.2.2 Suspend CORE Immediately ALTERATIONS.
AND D.2.3 Initiate action to Immediately suspend OPDRVs.(continued)
LaSalle 1 and 2 3.7.5-2 Amendment No. 188/175 Control Room Area Ventilation AC System 3.7.5 ACTIONS CONDITION REQU I RED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition B not met during movement of irradiated fuel assemblies in the secondary containment, during CORE ALTERATIONS, or during OPDRVs.
NOTE LCO 3.0.3 is not applicable.
E.1 Suspend movement of irradiated fuel assemblies in the secondary containment.
Immediately E.2 Suspend CORE A L TE RA TI aN S . Immediately E.3 Initiate action suspend OPDRVs. to Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.5.1 Monitor control room and auxiliary electric equipment room temperatures.
In accordance with the Surveillance Frequency Control Program SR 3.7.5.2 Verify correct breaker alignment and indicated power are available to the control room area ventilation AC subsystems.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.7.5-3 Amendment No. 200/ 187 Main Condenser Offgas 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Condenser Offgas LCO 3.7.6 The gross gamma activity rate of the noble gases measured prior to the holdup line shall be s 340,000 pCi/second after decay of 30 minutes.APPLICABILITY:
MODE 1, MODES 2 and 3 with steam jet air any main steam line not isolated and ejector (SJAE) in operation.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma activity A.1 Restore gross gamma 72 hours rate of the noble activity rate of the gases not within noble gases to within limit, limit.B. Required Action and B.1 Isolate all main 12 hours associated Completion steam lines.Time not met.OR B.2 Isolate SJAE. 12 hours OR B.3 Be in MODE 3. 12 hours I I LaSalle I and 2 3.7.6-1 Amendment No. 184 /171 Main Condenser Offgas 3.7.6 SURVEILLANCE REQUIREMENTS SURVEI SR 3.7.6.1 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 s 340,000 after decay of 30 minutes.
In accordance with the Surveillance Frequency Control Program Once withi n 4 hours after a 50% increase in the nominal steady state fission gas rel ease after factoring out increases due to changes in THERMAL POWER 1 eve 1 LaSalle 1 and 2 3.7.6-2 Amendment No.200 / 187 Main Turbine Bypass System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Main Turbine Bypass System LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE.
LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPRl," limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.
APPLICABILITY:
TH RMAL POWER 25% RTP. ACTIONS CONDITION REQU I RED ACTI ON N TIME A. Requirements of the LCO not met. A.1 Satisfy the requirements of the LCD. 2 hours B. Required Action and associated Completion Time not met. B.1 Reduce THERMAL POWER to < 25% RTP. 4 hours SURVEILLANCE SR 3.7.7.1 Verify one complete cycle of each main turbine bypass valve.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.7.7-1 Amendment No. 200/ 187 Main Turbine Bypass System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Program SR 3.7.7.3 Verify the TURBINE BYPASS SYSTEM RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.7.7-2 Amendment No200 / 187 Spent Fuel Storage Pool Water Level 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Spent Fuel Storage Pool Water Level LCO The spent fuel storage pool water 1 evel shall be 21 ft 4 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks. APPLICABI LITY: During movement of irradiated fuel assemblies in the spent fuel storage pool, During movement of new fuel assemblies in the spent fuel storage pool with irradiated fuel assemblies seated in the spent fuel storage pool. ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. Spent fuel storage pool water level not within limit. A.l NOTE -LCO 3.0.3 is not applicable.
Suspend movement of fuel assemblies in the spent fuel storage pool. Immediately SURVEILLANCE SR Verify the spent fuel storage pool water level is 21 ft 4 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.7.8-1 Amendment No.200 / 187 AC Sources-Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:-a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electric Power Distribution System;b. Three diesel generators (DGs); and c. The opposite unit's Division 2 DG capable of supporting the associated equipment required to be OPERABLE by LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," LCO 3.7.4, "Control Room Area Filtration (CRAF) System," and LCO 3.7.5, "Control Room Area Ventilation Air Conditioning (AC) System." APPLICABILITY:
MODES 1, 2, and 3.----------------------------
NOTES---------------------------
: 1. Division 3 AC electrical power sources are not required to be OPERABLE when High Pressure Core Spray (HPCS)System is inoperable.
: 2. The opposite unit's Division 2 DG in LCO 3.8.1.c is not required to be OPERABLE when the associated required equipment is inoperable.
-- ----- .-- -- ----- ------ ---.-- ---LaSalle I and 2 3.8.1-1 Amendment No. / 172/158 AC Sources-Operating 3.8.1 ACTIONS-,, ------------
NOTE----------------------------------
LCO 3.0.4.b is not applicable to DGs.----------------------------------------
-------r 7----------------------------
CONDITION REQUIRED ACTION COMPLETION -TIME A. One required offsite A.1 Perform SR 3.8.1.1 1 hour circuit inoperable.
for OPERABLE required offsite circuit. AND Once per 8 hours thereafter A.2 Declare required 24 hours from feature(s) with no discovery of no offsite power offsite power*available inoperable to one division when the redundant concurrent with required feature(s) inoperability are inoperable.
of redundant required feature(s)
AND~A.3 Restore required 72 hours offsite circuit to OPERABLE status. A 17 days from discovery of failure to meet LCO 3.8.1.a or b (continued)
LaSalle 1 and 2 3.8.1-2 Amendment No. /171/157 AC Sources- Operating 3.8.1 ArTIONS CONDITION
[ REQUIRED ACTION COMPLETION TIME B. One required Division 1. or 2 DG inoperable.
OR Required opposite unit Division 2 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(s). inoperable when the redundant required feature(s) are inoperable.
AND 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 1 hour AND Once per 8 hours thereafter 4 hours from discovery of Condition B concurrent with inoperability of redundant required feature(s) 24 hours 24 hours 14 days AND 17 days from discovery of failure to meet LCO 3.8.1.a or b B.4 Restore required DG(s) to OPERABLE status.(continued)
LaSalle I and 2 3.8.1-3 Amendment No. 150/136 JAN 3 0 2002 AC Sources-Operating 3.8.1 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME C. Required Division 3 DG inoperable.
One required Division 1, 2, 0 r 3 DG inoperable and the required opposite unit Division 2 DG inoperable.
C.1 AND C.2 Perform SR 3.8.1.1 for OPERABLE required offsite circuit(s).
Declare required feature(s), supported by the inoperable DG(s), inoperable when the redundant required feature(s) are inoperable.
1 hour AND Once per 8 hours thereafter 4 hours from discovery of Condition C concurrent with inoperability of redundant required feature(s)
C.3.1 OR C.3.2 Determine OPERABLE DG(s) are not inoperable due to common cause failure. Perform SR 3.8.1.2 for OPERABLE DG(s). 24 hours 24 hours C.4 Restore required DG(s) to OPERABLE status. 72 hours 17 days from discovery of failure to meet LCO 3.8.La or b (continued)
LaSalle 1 and 2 3.8.1-4 Amendment No. 194/181 AC Sources -Operating 3.8.1 X~ ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME 4. 4 D. Two required offsite circuits inoperable.
D.1 Declare required feature(s) inoperable when the redundant required feature(s) are inoperable.
12 hours from discovery of Condition D concurrent with inoperability of redundant required feature(s) 24 hours AND D.2 Restore one required offsite circuit to OPERABLE status.+E. One required offsite circuit inoperable.
AND One required Division 1, 2, or 3 DG inoperable.
------------
NOTE-------------
Enter applicable Conditions and Required Actions of LCO 3.8.7. 'Distribution Systems -Operating," when Condition E is entered with no AC power source to any required division.E.1 Restore required offsite circuit to OPERABLE status.12 hours 12 hours OR E.2 Restore required DG to OPERABLE status.(continued)
LaSalle I and 2 3.8.1-5 Amendment No. 147/133 AC Sources-Operating 3.8.1 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME F. Two required Division 1, 2, or 3 DGs inoperable. .DR Division 2 DG and the required opposite unit Division 2 DG inoperable.
F.l Restore one required DG to OPERABLE status. 2 hours 72 hours if Division 3 DG is inoperable G. Required Action and associated Completion Time of Condition A, B, C, D, E, or F not met. G.l Be in MODE 3. 12 hours H. Three or more required AC sources inoperable.
H.l Enter LCO 3.0.3. Immediately LaSalle 1 and 2 3.8.1-6 Amendment  194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS
---------------
------------NOTES
---------------------SR 3.8.1.1 through SR 3.8.1.20 are applicable only to the given unit's AC electrical power sources. SR 3.8.1.21 is applicable to the required opposite unit's DG. SR 3.8.1.1 SURVEILLANCE Verify correct breaker alignment indicated power availability for required offsite circuit. and each FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.8.1.2 1. 2. 3. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. 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. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG starts from standby conditions and achieves steady state voltage 4010 V and 4310 V and frequency 58.8 Hz and 61.2 Hz. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.8.1 7 Amendment No.200 I 187 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------
NOTES------DG loadings may include gradual loading as recommended by the manufacturer. Momentary transients outside the load range do not invalidate this test. This Surveillance shall be conducted on only one DG at a time. 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. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG is synchronized and In accordance loaded and operates for 2 60 minutes at a with the load 2 2400 kW and 2600 kW. Surveillance Frequency Control Program SR 3.8.1.4 Verify each required day tank contains In accordance 2250 gal of fuel oil for Divisions 1 and 2 with the and 2 550 gal for Division 3. Surveillance Frequency Control Program In accordance each required day tank. SR 3.8.1.5 Check for and remove accumulated water from with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.8.1-8 Amendment No. 200/ 187 3.8.1 AC Sources-Operating SURVEILLANCE REQUIREMENTS SU RVEI LLANC E FREQUENCY SR 3.8.1.6 Verify each required fuel oil transfer system operates to automatically transfer fuel oi 1 from storage tanks to the day tank. In accordance with the Surveillance Frequency Control Program SR 3.8.1.7 1. 2.
All DG starts may be preceded by an engine prelube period. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG starts from standby condition and achieves:
: a. In 13 seconds, voltage 4010 V and frequency 58.8 Hz; and b. Steady state voltage 4010 V and 4310 V and frequency 58.8 Hz and 61.2 Hz. In accordance with the Surveillance Frequency Control Program SR 3.8.1.8 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 manual transfer of unit power supply from the normal offsite circuit to the alternate offsite circuit. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.1-9 Amendment No 200/ 187 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.9
: 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. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG r ects a load greater than or equal to its associated single largest post accident load and following load rejection, the frequency is $ 66.7 Hz. In accordance with the Surveillance Frequency Control Program SR 3.8.1.10
: 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. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG does not trip and voltage is maintained
$ 5000 V during and following a load rejection of a load 2600 kW. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.1-10 Amendment No. 2001 187 AC Sources-Operating 3.8.1 SURVEILLANCE FREQUENCY 3.8.1.11 In accordance with the Surveillance Frequency Control Program SURVEILLANCE
-NOTES All DG starts may be preceded by an engine prelube period. 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 loss of offsite power signal: De-energization of emergency buses; Load shedding from emergency buses for Divisions 1 and 2 only; and DG auto-starts from standby condition and: energizes permanently connected loads in 13 seconds, energizes auto-connected shutdown loads, maintains steady state voltage 4010 V and 4310 V, maintains steady state frequency 58.8 Hz and 61.2 Hz, and supplies permanently connected and auto-connected shutdown loads for 5 minutes. (continued)
LaSalle 1 and 3.8.1-11 Amendment No 200 / 187 AC Sources-Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.12 In accordance the Surveillance Frequency Control Program SURVEILLANCE
------------------NOTES------All DG starts may be preceded by an engine prelube period. 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 required DG auto-starts from standby condition and: In 13 seconds after auto-start, achieves voltage 4010 V and frequency 58.8 Hz; Achieves steady state voltage 10 V and 4310 V and frequency 58.8 Hz and 61.2 Hz; and Operates for 5 minutes. (continued)
LaSalle 1 and 3.8.1-12 Amendment No.200 I 187 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SR -------------------
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 each required DG's automatic trips are bypassed on an actual or simulated ECCS initiation signal except: a. Engine overspeed; and b. Generator differential current.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.1-13 Amendment No.200 / 187 AC Sources-Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.14 In accordance the Surveillance Frequency Control Program SURVEI LLANCE -------------------NOTES Momentary transients outside the load and power factor ranges do not invalidate this test. This Surveillance shall not normally be performed in MODE 1 or 2 unless the other two DGs are OPERABLE.
If either of the other two DGs becomes inoperable, this Surveillance shall be suspended.
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. 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. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG operating within the power factor limit operates for 2 24 hours: For 2 2 hours loaded 2 2860 kW; and For the remaining hours of the test loaded 2 2400 kW and 2600 kW. (continued)
LaSalle 1 and 3.8.1-14 Amendment No. 200 / 187 AC Source rating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.15 In accordance the Surveillance Frequency Control Program SURVEILLANCE NOTES ----------This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 2 hours loaded 2 2400 kW and 2600 kW. Momentary transients outside of load range do not invalidate this test. 2 All DG sta rts may be preceded by an engine prelube period. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG starts and achieves: In 13 seconds, voltage 2 4010 V and frequency 2 58.8 Hz; and Steady state voltage 2 4010 V and 4310 V and frequency 2 58.8 Hz and 61.2 Hz. (continued)
LaSalle 1 and 3.8.1-15 Amendment No200 / 187 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SR SURVEI 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 each required DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power; b. Transfers loads source; and to offsite power c. Returns to ready-to load operation.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.1-16 Amendment No. 200 1 187 3.8.1 AC Sources-Operating SURVEILLANCE REQUIREMENTS SR 3.8.1.17 SURVEILLANCE --NOTE-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. FREQUENCY Verify, with a required DG operating in test mode and connected to its bus: a. For Division 1 and 2 DGs, an actual or simulated ECCS initiation signal overrides the test mode by returning DG to ready-to-load operation; and b. For Division 3 DG, an actual or simulated DG overcurrent trip signal automatically disconnects the offsite power source while the DG continues to supply normal loads. In accordance with the Surveillance Frequency Control Program SR 3.8.1.18 -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 interval between each sequenced load block, for Division 1 and 2 DGs only, is 2 90% of the design interval for each time delay relay. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.1 17 Amendment NO*200 /187 AC Sources-Operating 3.8.1 SURVEILLANCE FREQUENCY 3.8.1.19 In accordance the Surveillance Frequency Control Program SURVEI LLANCE All DG starts may be preceded by an engine prelube period. 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 loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: De-energization of emergency buses; Load shedding from emergency buses for Divisions 1 and 2 only; and DG auto starts from standby condition and: energizes permanently connected loads in 13 seconds, energizes auto-connected emergency loads including through time delay relays, where applicable, maintains steady state voltage 4010 V and 4310 V, maintains steady state frequency 58.8 Hz and 61.2 Hz, and supplies permanently connected and auto connected emergency loads for 5 minutes. (continued)
LaSalle 1 and 3.8.1-18 Amendment No. 200 / 187 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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 required DG achieves, in 13 seconds, voltage 4010 V and frequency 58.8 Hz. In accordance with the Surveillance Frequency Cont ro1 P rog ram SR 3.8.1.21 -NOTE When the opposite unit is in MODE 4 or 5, or moving irradiated fuel assemblies in secondary containment, the following opposite unit SRs are not required to be performed:
SR 3.8.1.3, SR 3.8.1.9 through SR 3.8.1.11, SR 3.8.1.14 through SR 3.8.1.16.
For required opposite unit DG, the SRs of the opposite unit's Specification 3.8.1, except SR 3.8.1.12, SR 3.8.1.13, SR 3.8.1.17, SR 3.8.1.18, SR 3.8.1.19, and SR 3.8.1.20, are applicable.
In accordance with applicable SRs LaSalle 1 and 2 3.8.1-19 Amendment No.200 / 187 AC Sources -Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources -Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE: a. One qualified circuit between the offsite transmission network and the onsite Class IE AC electrical power distribution subsystem(s) required by LCO 3.8.8,'Distribution Systems- Shutdown";
and b. One diesel generator (DG) capable of supplying one division of the Division 1 or 2 onsite Class IE AC electrical power distribution subsystem(s) required by LCO 3.8.8: c. The Division 3 DG capable of supplying the Division 3 onsite Class IE AC electrical power distribution subsystem, when the Division 3 onsite Class lE AC electrical power distribution subsystem is required by LCO 3.8.8; and d. One qualified circuit, which may be the same circuit in LCO 3.8.2.a. between the offsite transmission network and the opposite unit Division 2 onsite Class lE AC electrical power distribution subsystem, or the opposite unit DG capable of supplying the opposite unit Division 2 onsite Class lE AC electrical power distribution subsystem, when the opposite unit Division 2 onsite Class 1E AC electrical power distribution subsystem is required by LCO 3.8.8.APPLICABILITY:
MODES 4 and 5.During movement of irradiated fuel assemblies in the secondary containment.
LaSalle 1 and 2 3.8.2 -1 Amendment No. 147/133 AC Sources -Shutdown 3.8.2 ACTIONS------------------------------------
NOTE-----------------------------------
LCO 3.0.3 is not applicable.
--- ------------------------------------CONDITION REQUIRED ACTION COMPLETION TIME A. Required offsite-----------NOTE------------
circuit of LCO Item a. Enter applicable Condition inoperable.
and Required Actions of LCO 3.8.8, when any required division is de-energized as a result of Condition A.A.1 Declare affected Immediately required feature(s) with no offsite power available inoperable.
OR A.2.1 Suspend CORE Immediately ALTERATIONS.
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.
AND (continued)
LaSalle I and 2 3.8.2-2 Amendment No. 147/133 AC Sources -Shutdown 3.8.2 ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. (continued)
A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel (OPDRVs).AND A.2.4 Initiate action to Immediately restore required offsite power circuit to OPERABLE status.B. Required DG of LCO B.1 Suspend CORE Immediately Item b. inoperable.
ALTERATIONS..
AND B.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment.
AND B.3 Initiate action to Immediately suspend OPDRVs.AND B.4 Initiate action to Immediately restore required OG to OPERABLE status.C. Required DG of LCO C.1 Declare High Pressure 72 hours Item c. inoperable.
Core Spray System inoperable.(continued)
LaSalle I and 2 3.8.2-3 Amendmenet No. 147/133 AC Sources -Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required offsite D.1 Declare associated Immediately circuit or DG of LCO standby gas treatment Item d. inoperable.
subsystem, control room area filtration subsystem, and control room area ventilation air conditioning subsystem inoperable.
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 In accordance SRs of Specification 3.8.1, except with applicable SR 3.8.1.8, SR 3.8.1.17, and SR 3.8.1.20, SRs are applicable.
LaSalle I and 2 3.8.2 -4 Amendment No. 147/133 Diesel Fuel Oil and Starting Ai r 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil and Starting Air LCO The stored diesel fuel oil and starting air subsystem shall be within limits for each required diesel generator (DG). APPLICABI When associated DG is required to be OPERABLE.
-------------------------------------
NOT E------------------------------------
Separate Condition entry is allowed for each DG. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.l Restore stored fuel 48 hours stored fuel oi 1 1 evel : oil level to within 1 i mit. 1. In the combi ned day tank and fuel oi 1 storage tank for the Division 1 and Division 2 DGs, and the opposite unit Division 2 DG, less than a 7-day supply and greater than or equal to a 6-day supply; and 2. In the combi ned day tank and fuel oi 1 storage tank for the Division 3 DG, less than a 7-day supply and greater than or equal to a 6-day supply. (continued)
LaSalle 1 and 3.8.3-1 Amendment No. 191/178 Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or more DGs with 8.1 Restore stored fuel 7 days stored fuel oil total oil total particulates not particulates to within limit. within limit.C. One or more DGs with C.1 Restore stored fuel 30 days new fuel oil oil properties to properties not within within limits.limits.D. One or more DGs with D.1 Restore starting air 48 hours starting air receiver receiver pressure to pressure < 200 psig > 200 psig.and > 165 psig.E. Required Action and E.1 Declare associated DG Immediately associated Completion inoperable.
Time of Condition A, B. C, or D not met.OR One or more DGs with stored diesel fuel oil or starting air subsystem not within limits for reasons other than Condition A, B. C, or D.LaSalle I and 2 3.8.3- 2 Amendment No. 147/133 Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify: a. a 7 day supply of fuel in the combi ned fuel oi 1 storage tank and day tank for the Division 1 and Division 2 OGs and the opposite unit Division 2 DG. b. a 7 day supply of fuel in the combined fuel oil storage tank and day tank for the Division 3 DG. In accordance with the Surveillance Frequency Control Program SR 3.8.3.2 Veri fy 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 Oi esel Fuel Oil Testing Program SR 3.8.3.3 Verify each DG is 200 psig. air start receiver pressure In accordance with the Surveillance Frequency Control Program SR 3.8.3.4 Check for each fuel and remove accumulated 0; 1 storage tank. water from In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.8.3-3 Amendment NO*200 / 187 DC Sources-Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources-Operating LCO 3.8.4 APPLICABILITY:
The Division 1 125 VDC and 250 VDC, Division 2 125 VDC, Division 3 125 VDC, and the opposite unit Division 2 125 VDC electrical power subsystems shall be OPERABLE.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required Division A.1 Restore battery 2 hours 1, 2, or 3 125 VDC terminal voltage to battery charger on one greater than or equal-d-i-v-is-ian-n pre-r-a-b-l-e-.
t--t-h-e-m-i-n--m-established float OR voltage.One required Division AND 2 or opposite unit Division 2 battery A.2 Verify battery float Once per 12 charger on one current < 2 amps. hours division inoperable.
OR One required Division AND 1 250 VDC battery* charger inoperable.
A.3 Restore required 7 days battery charger(s) to OPERABLE status.B. Division 1 or 2 B.1 Restore Division 1 2 hours 125 VDC. electrical and 2 125 VDC power subsystem electrical power inoperable for reasons subsystems to other than Condition OPERABLE status.A.(continued)
LaSalle I and 2 3.8.4-1 Amendment No'.179/165 DC Sources-Operating 3.8.4 CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Declare High Pressure Immediately associated Completion Core Spray System Time of Condition A inoperable.
not met for the Division 3 DC electrical power subsystem.
OR Division 3 DC electrical power subsystem inoperable for reasons other than Condition A.D. Required Action and D.1 Declare associated Immediately associated Completion supported features Time of Condition A inoperable.
not met for the Division 1 250 VDC electrical power subsystem.
OR Division 1 250 VDC electrical power subsystem inoperable for reasons other than Condition A.E. Required Action and E.1 Restore opposite unit 7 days associated Completion Division 2 DC Time of Condition A electrical power not met for the ,subsystem to OPERABLE opposite unit Division status.2 DC electrical power subsystem.
OR Opposite unit Division 2 DC electrical power subsystem inoperable for reasons other than Condition A.(continued)
LaSalle 1 and 2 3.8.4-2 Amendment No.179/165 DC Sources-Operating 3.8.4 ACTI ONS CONDITION REQUIRED ACTION COMPLET ION TIME F. Required Ac associated Completion Time of Con not met for Division 1 VDC electrical subsystem.
OR Required Action associated Time of not met. Con tion and dition A the or 2 125 power and Completion E dition F.l AND F.2 Be in MODE 3. Be in MODE 4. 12 hours 36 hours G. Required Ac associated Completion Time of not met. Con tion and B dition G .1 Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS
-------------------------------NOTES I. SR 3.8.4.1 electrical through SR 3.8.4.3 power sources. are applicable only to the given un t's DC 2. SR 3.8.4.4 source. is applicable only to the opposite unit DC electrical power SR Verify battery terminal voltage is greater than or equal to the minimum established float voltage.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.8.4-3 Amendment No.200 I 187 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SR SURVEI Verify each required battery charger supplies:
: a. 200 amps at greater than or equal to the minimum established float voltage for 4 hours for the Division 1 and 2 125 V battery chargers;
: b. 50 amps at greater than or equal to the minimum established float voltage for 4 hours for the Division 3 125 V battery charger; and c. 200 amps at greater than or equal to the minimum established float voltage for 4 hours for the 250 V battery charger. 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.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.4-4 Amendment No. 200 I 187 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.3 -NOTES 1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3. 2. This Surveillance shall not normally be performed in MODE 1 or 2 for the 125 VDC batteries.
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. In accordance with the Surveillance Frequency Control Program SR 3.8.4.4 ---NOTE When the opposite unit is in MODE 4 or 5, or moving irradiated fuel in the secondary containment, the following opposite unit SRs are not required to be performed:
SR 3.8.4.2 and SR 3.8.4.3. For the opposite unit Division 2 DC electrical power subsystem, the SRs of the opposite unit Specification 3.8.4 are applicable.
In accordance with applicable SRs LaSall eland 2 3.8.4-5 Amendment No 200 / 187 DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.9 ------------------
NOTE---------------------
When the opposite unit is in MODE 4 or 5.or moving irradiated fuel in the secondary containment.
the following opposite unit SRs are not required to be performed:
SR 3.8.4.6. SR 3.8.4.7. and SR 3.8.4.8.For the opposite unit Division 2 DC In accordance electrical power subsystem, the SRs of the with applicable opposite unit Specification 3.8.4 are SRs applicable.
LaSalle 1 and 2 3.8.4-6 Amendment No. 147/133 DC Sources -Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources -Shutdown LCO 3.8.5 The following DC electrical power subsystem(s) shall be OPERABLE: a. One Division 1 125 VDC or Division 2 125 VDC electrical power subsystem capable of supplying one division of the onsite Class lE DC Electrical Power Distribution System required by LCO 3.8.8. "Distribution Systems -Shutdown":
: b. The Division 3 125 VDC electrical power subsystem, when the Division 3 onsite Class 1E DC electrical power distribution subsystem is required by LCO 3.8.8; and c. The opposite unit Division 2 125 VDC electrical power distribution subsystem, when the opposite unit Division 2 onsite Class 1E DC electrical power distribution subsystem is required by LCO 3.8.8.APPLICABILITY:
MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.
LaSalle 1 and 2 3.8.5-1 Amendment No. 147/133 DC Sources-Shutdown 3.8.5 ACTIONS---------NOTE-LCO 3.0.3 is not applicable.
CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Restore required 2 hours battery charger battery terminal on one division voltage to greater inoperable, than or equal to the minimum established float voltage.AND AND The redundant A.2 Verify required Once per 12 required division battery float current hours battery and < 2 amps.charger OPERABLE.AND A.3 Restore required 7 days battery charger to OPERABLE status.(continued)
LaSalle 1 and 2 3.8.5-2 Amendment No 479 465 DC Sources-Shutdown 3.8.5 ACTIONS CONDITION
[ REQUIRED ACTION [ COMPLETION TIME B. One or more required DC electrical power subsystems inoperable for reasons other than Condition A.OR Required Action and 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 irradiated fuel assemblies in the 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 LaSalle I and 2 3.8.5-3 Amendment No179 /165 DC Sources-Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1----------
---------NOTE-----------------
The following SRs are not required to be performed:
SR 3.8.4.2 and SR 3.8.4.3.For DC electrical power subsystems required to be OPERABLE the following SRs are applicable:
SR 3.8.4.1, SR 3.8.4.2, SR 3.8.4.3, and SR 3.8.4.4.In accordance with applicable SRs LaSalle 1 and 2 3.8.5-4 Amendment No.179 465 Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.8.6 APPLICABILITY:
Battery parameters for the Division 1, 2, and 3 and opposite unit Division 2 batteries shall be within limits.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 More batteries A.1 Perform SR 3.8.4.1. 2 hours with one or more battery cells float AND voltage < 2.07 V.A.2 Perform SR 3.8.6.1. 2 hours AND A.3 Restore affected cell 24 hours voltage 2 2.07 V.B. One or more batteries B.1 Perform SR 3.8.4.1. 2 hours with float current >2 amps. AND B.2 Restore battery float 12 hours current to  2 amps.(continued)
LaSalle I and 2 3.8.6-1 Amendment N.1 7 9/165 Battery Parameters 3.8.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME--- -- ----Note----------
-------------
Note-----------
Required Action C.2 shall Required Action C.1 and C.2 be completed if are only applicable if electrolyte level was electrolyte level was below below top of plates. the top of plates C. One or more batteries C.1 Restore electrolyte 8 hours with one or more level to above top of cells electrolyte plates.level less than minimum established AND design limits.C.2 Verify no evidence of 12 hours leakage.AND C.3 Restore electrolyte 31 days level to greater than or equal to minimum established design limits.D. One or more batteries D.1 Restore battery pilot 12 hours with pilot cell cell temperature to electrolyte greater than or equal temperature less than to minimum minimum established established des.ign design limits, limits.E. Two or more redundant E.1 Restore battery 2 hours division batteries parameters for with battery affected battery in parameters not within one division to limits, within limits.(continued)
LaSalle I and 2 3.8.6-2 Amendment No179/165 Battery Parameters 3.8.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and associated Completion Time of Condition A, B, C, D, or E not met. F.1 Declare associated battery inoperable.
Immediately One or more batteries with one or more battery cells float voltage < 2.07 V and float current> 2 amps. SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.6.1 ------------------
NOT E------------------
Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1. Verify battery float current is S 2 amps. In accordance with the Surveillance Frequency Control Program SR 3.8.6.2 Verify each battery pilot cell voltage is 2: 2.07 V. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.6-3 Amendment No. 200 / 187 Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.3 Verify each battery connected cell electrolyte level is greater than or equal to minimum established design limits. 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. In accordance with the Surveillance Frequency Control Program SR 3.8.6.5 Verify each battery connected cell voltage is ;?: 2.07 V. In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.8.6-4 Amendment NO.200 I 187 Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SR --------NOTES ------------This Surveillance shall not normally be performed in MODE 1 or 2 for the 125 VDC batteries.
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. In MODE 1, 2 or 3, and the opposite unit in MODE 4 or 5, or moving irradiated fuel in the secondary containment, this Surveillance is not required to be performed for the opposite unit Division 2 DC electrical power subsystem. In MODE 4, 5 or during movement of irradiated fuel in the secondary containment in Mode 4, 5 or defueled, this Surveillance is not required to be performed.
Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test. FR In accordance with the Surveillance Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of the life with capacity 100% of manufacturer's rating LaSalle 1 and 3.8.6-5 Amendment No. 200 / 187 Distribution Systems-Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Distribution Systems-Operating LCO 3.8.7 The following electrical power distribution subsystems shall be OPERABLE: a. Division I and Division 2 AC and 125 V DC distribution subsystems;
: b. Division 3 AC and 125 V DC distribution subsystems; C. Division 1 250 V DC distribution subsystem; and d. The portions of the opposite unit's Division 2 AC and 125 V DC electrical power distribution subsystems capable of supporting the equipment required to be OPERABLE by LCO 3.6.4.3, "Standby Gas Treatment (SGT)System," LCO 3.7.4, "Control Room Area Filtration (CRAF)System," LCO 3.7.5, "Control Room Area Ventilation Air Conditioning (AC) System," and LCO 3.8.1,"AC Sourtes-Operating." I APPLICABILITY:
MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both Division I A.1 Restore Division 1 8 hours and 2 AC electrical and 2 AC electrical power distribution power distribution QfD subsystems inoperable.
subsystems to OPERABLE status. 16 hours from discovery of failure to meet LCO 3.8.7.a (continued)
LaSalle I and 2 3 .8.7-1 Amendment No. /172/158 Distribution Systems-Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or both Division 1 B.1 Restore Division 1 2 hours and 2 125 V DC and 2 125 V DC electrical power electrical power AND distribution distribution subsystems inoperable, subsystem(s) to 16 hours from OPERABLE status. discovery of failure to meet LCO 3.8.7.a C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B not met.D. One or more required --------------
NOTE----------
opposite unit Division Enter applicable Conditions 2 AC or DC electrical and Required Actions of LCO power distribution 3.8.1 when Condition C subsystems inoperable, results in the inoperability of a required offsite circuit.D.1 Restore required 7 days opposite unit Division 2 AC and DC electrical power distribution subsystem(s).
E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition D AND not met.E.2 Be in MODE 4. 36 hours (continued)
I ~ U ri~d ,2-~Amendnt No. .184 A 71 Distribution 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. One or both Division 3 AC or DC electrical power distribution subsystems inoperable.
F.l Declare associated supported features inoperable.
Immediately G. Division 1 250 V DC electrical power subsystem inoperable.
G.1 Declare associated supported features inoperable.
Immediately H. Two or more electrical power distribution subsystems inoperable that, in combination, result in a loss of function.
H.l Enter LCO 3.0.3. Immediately SURVEILLANCE SR Verify correct breaker alignments and voltage to required AC and DC electrical power distribution subsystems.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.8.7-3 Amendment No. 200 I 187 Distribution Systems -Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems-Shutdown LCO 3.8.8 APPLICABILITY:
The necessary portions of the Division 1. Division 2. and Division 3 AC and DC, and the opposite unit Division 2 AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS-.- ------------------------
NOTE-------------------------------------
LCO 3.0.3 is not applicable.
-----------------------------------------------------------.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC or DC electrical supported required power distribution feature(s) subsystems inoperable.
inoperable.
OR A.2.1 Suspend CORE Immediately ALTERATIONS.
AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.
AND (continued)
LaSalle 1 and 2 3.8.8-1 Amendment No. 147/133 Distribution Systems-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel. Immediately A.2.4 Initiate actions to restore required AC and DC electrical power distribution subsystems to OPERABLE status. Immediately A.2.S Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.
Immediately SURVEILLANCE SR Verify correct breaker alignments and voltage to required AC and DC electrical power distribution subsystems.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.8.8-2 Amendment N0200 / 187 Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks LCO 3.9.1 APPLICABILITY:
The refueling equipment interlocks associated with the reactor mode switch refuel position shall be OPERABLE.During in-vessel fuel movement with equipment associated with the interlocks when reactor mode switch is in the refuel position.ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend in-vessel Immediately refueling equipment fuel movement with interlocks inoperable.
equipment associated with the inoperable interlock(s).
OR A.2.1 Insert a control rod Immediately withdrawal block.AND A.2.2 Verify all control Immediately rods are fully inserted.La.Salle 1 and 2 3.9.1 -1 Amendment No. 147/133 Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.9.1.1 In accordance with the Surveillance Frequency Control Program SURVEI LLANCE Perform CHANNEL FUNCTIONAL TEST on each of the following required refueling equipment interlock inputs: All rods-in, Refuel platform position, Refuel platform fuel grapple, fuel loaded, Refuel platform frame mounted hoist, fuel-loaded, Refuel platform trolley-mounted hoist, fuel loaded, and Service platform hoist, fuel-loaded.
LaSall eland 3.9.1-2 Amendment No. 2001 187 Refuel Position One-Rod Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod Out LCD 3.9.2 The refuel position one-rod out interlock shall be APPLICABILITY: 5 with the reactor mode switch in the refuel position and any control rod withdrawn.
ACTIONS CONDITION REQU I RED ACTION COMP LETI ON TI ME A. Refuel position rod out interlock inoperable.
A.1 A.2 Suspend control rod withdrawal.
Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies.
Immediately Immediately SURVEILLANCE SR 3.9.2.1 Verify reactor mode switch locked in refuel position.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 3.9.2-1 Amendment No.2DD / 187 Refuel Position One Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS SR 3.9.2.2 --NOTE Not required to be performed until 1 hour after any control rod is withdrawn.
Perform CHANNEL FUNCTIONAL TEST.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.2-2 Amendment No. 200/ 187 Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod LCO 3.9.3 All control rods shall be full y APPLICABI LITY: When loading fuel assemblies into the core. ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. One or more control rods not fully inserted.
A.l Suspend loading fuel assemblies into the core. Immediately SURVEILLANCE SURVEI LLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.3 1 Amendment No.200 / 187 Control Rod Position Indication 3.9.4' I 3.9 REFUELING OPERATIONS 3.9.4 Control Rod Position Indication LCO 3.9.4 APPLICABILITY:
The control rod "full-in" position indication channel for each control rod shall be OPERABLE.MODE 5.ACTIONS-.--------------------------
NOTE------------------------------------
Separate Condition entry is allowed for each required channel.-----------------------------------------------------------.CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control A.1.1 Suspend in-vessel Immediately rod position fuel movement.indication channels inoperable.
AND A.1.2 Suspend control rod Immediately withdrawal.
AND A.1.3 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.
OR (continued)
La~alle 1 and 2 3.9.4-1 Amendment No. 147/133 Control Rod Position Indication 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2.1 Initiate action to Immediately fully insert the control rod associated with the inoperable position indicator.
AND A.2.2 Initiate action to Immediately disarm the control rod drive associated with the fully inserted control rod.SURVEILLANCE REOUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify the channel has no "full- in" Each time the indication on each control rod that is not control rod is'full-in." withdrawn from the "full-in'position LaSalle I and 2 3.9.4-2 Amendment No. 147/133 Control Rod OPERABILITY-Refueling 3.9.5 3.9 REFUELING 3.9.5 Control OPERATIONS Rod OPERABILITY-Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.
APPLICABI LITY: ACTIONS MODE 5. CONDITION REQUIRED ACTION COMPLETION TIlvlE A. One or more withdrawn control rods inoperable.
A.l Initiate action to fully insert inoperable withdrawn control rods. Immediately SURVEILLANCE 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. In accordance with the Surveillance Frequency Control Program SR 3.9.5.2 Verify each withdrawn control rod scram accumulator pressure is 940 psig. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.5 1 Amendment No. 200 / 187 RPV Water Level-Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level-Irradiated Fuel LCO 3.9.6 RPV water level shall be 22 ft above the top of the RPV fl ange. APPLICABI LITY: During movement of irradiated fuel assemblies within the RPV. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within 1 imit. A.l Suspend movement of i rradi ated fuel assemblies within the RPV. Immediately SURVEILLANCE SR 3.9.6.1 Verify RPV water level is 22 ft above the top of the RPV fl ange.
In accordance wi th the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.6-1 Amendment No.200 I 187 RPV Water Level-New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods LCO RPV water 1 evel shall be 23 ft above the top of i rradi ated fuel assemblies seated within the RPV. APPLICABI LITY: 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 1 evel not within limit. A.l Suspend movement of new fuel assemblies and handling of control rods within the RPV. Immediately SURVEILLANCE SURVEI SR 3.9.7.1 Verify RPV water level is 23 ft above the top of irradiated fuel assemblies seated withi n the RPV.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 3.9.7-1 Amendment No.200 I 187 RHR-High Water Level 3.9.8 3.9 REFUELING OPERATIONS 3.9.8 Residual Heat Removal (RHR) -High Water Level LCO 3.9.8 One RHR shutdown cooling subsystem shall be OPERABLE and in operation.
----------------------------
NOTE----------------------------
The required RHR shutdown cooling subsystem may be not in 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 above the top of the RPV flange.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required RHR shutdown A.1 Verify an alternate 1 hour cooling subsystem method of decay heat inoperable.
removal is available.
AND Once per 24 hours thereafter B. Required Action and B.1 Suspend loading Immediately associated Completion irradiated fuel Time of Condition A assemblies into the not met. RPV.AND (continued)
LaSalle I and 2 3.9.8-1 Amendment No. 147/133 RHR-High Water Level 3.9.8 K)ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)
B.2 Initiate action to Immediately restore secondary containment to OPERABLE status.AND B.3 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.AND B.4 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.C. No RHR shutdown C.1 Verify reactor 1 hour from cooling subsystem in coolant circulation discovery of no operation.
by an alternate reactor coolant method. circulation AND Once per 12 hours thereafter AND C.2 Monitor reactor Once per hour coolant temperature.
LaSalle 1 and 2 3.9.8-2 Amendment No. 147/133 SURVEILLANCE REQUIREMENTS SR 3.9.8.1 SR 3.9.8.2 SURVEILLANCE Verify one RHR shutdown cooling subsystem is operating.
Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. RHR-High Water Level 3.9.8 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.8-3 Amendment Nos. 214/200 RHR- Low Water Level 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Residual Heat Removal (RHR)- Low Water Level LCO 3.9.9 Two RHR shutdown cooling subsystems shall be OPERABLE.
and one RHR shutdown cooling subsystem shall be in operation.
---------------------------
NOTE----------------------------
The required operating shutdown cooling subsystem may be not in 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 above the top of the RPV flange.ACTIONS -_CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE---------
A.1 Verify an alternate 1 hour Separate Condition method of decay heat entry is allowed for removal is available AND each inoperable RHR for the inoperable shutdown cooling RHR shutdown cooling Once per subsystem.
subsystem.
24 hours thereafter One or two RHR shutdown cooling subsystems inoperable.
B. Required Action and B.1 Initiate action to Immediately associated Completion restore secondary Time of Condition A containment to not met. OPERABLE status.AND (continued)
LaSalle 1 and 2 3.9.9 -1 Amendment No. 147/133 RHR- Low Water Level 3.9.9 ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME B. (continued)
B.2 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.AND B.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.C. No RHR shutdown C.1 Verify reactor 1 hour from cooling subsystem in coolant circulation discovery of no operation.
by an alternate reactor coolant method. circulation AND Once per 12 hours thereafter AND C.2 Monitor reactor Once per hour coolant temperature.
LaSalle 1 and 2 3.9.9-2 Amendment No. 147/133 SURVEILLANCE REQUIREMENTS SR 3.9.9.1 SR 3.9.9.2 SURVEILLANCE Verify one RHR shutdown cooling subsystem is operating.
Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. RHR-Low Water Level 3.9.9 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.9-3 Amendment Reactor Mode Switch Interlock Testing 3.10.1 3.10 SPECIAL OPERATIONS 3.10.1 Reactor Mode Switch Interlock Testing LCO 3.10.1 The reactor mode switch position specified in Table 1.1-1 for MODES 3. 4, and 5 may be changed to include the run, startup/hot standby, and refuel position, and operation considered not to be in MODE 1 or 2, to allow testing of instrumentation associated with the reactor mode switch interlock functions, provided: a. All control rods remain fully inserted in core cells containing one or more fuel assemblies; and b. No CORE ALTERATIONS are in progress.APPLICABILITY:
MODES 3 and 4 with the reactor mode switch in the run.startup/hot standby, or refuel position, MODE 5 with the reactor mode switch in the run or startup/hot standby position.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend CORE Immediately above requirements not ALTERATIONS except met. for control rod insertion.
AND A.2 Fully insert all 1 hour insertable control rods in core cells containing one or more fuel assemblies.
AND (continued)
LaSalle I and 2 3.10.1-1I Amendment No. 147/133 Reactor Mode Switch Interlock Testing 3.10.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.3.1 Place the reactor mode switch in the shutdown position.
1 hour QR A.3.2 --
Only applicable in MODE 5. ----Place the reactor mode switch in the refuel position.
1 hour SURVEILLANCE SURVEI LLANCE FREQUENCY SR 3.10.1.1 Verify all control rods are fully inserted in core cells containing one or more fuel assemblies.
In accordance with the Surveillance Frequency Control Program SR 3.10.1.2 Verify no CORE ALTERATIONS are in progress.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.1 2 Amendment No.200 I 187 Single Control Rod Withdrawal -Hot Shutdown 3.10.2 3.10 SPECIAL OPERATIONS 3.10.2 Single Control Rod Withdrawal -Hot Shutdown LCO 3.10.2 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 I.a. 1.b, 7.a, 7.b. 10. and 11 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, at which time LCO 3.1.1. "SHUTDOWN MARGIN (SDM)," MODE 3 requirements.
may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.APPLICABILITY:
MODE 3 with the reactor mode switch in the refuel position.LaSalle 1 and 2 3.10.2-1 Amendment No. 147/133 Single Control Rod Withdrawal -Hot Shutdown 3.10.2 ACTIONS-------------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each requirement of the LCO.CONDITION REQUIRED ACTION I 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 LaSalle 1 and 2 3.10.2-2 Amendment No. 147/133 Single Control Rod Withdrawal-Hot Shutdown 3.10.2 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.10.2.1 Perform the applicable SRs LCOs. for the required According to the applicable SRs SR 3.10.2.2 Not required to be met if SR 3.10.2.1 is satisfied for LCO 3.10.2.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.
In accordance with the Surveillance Frequency Control Program SR 3.10.2.3 Verify all control rods, other than the control rod being withdrawn, are fully inserted.
In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.2-3 Amendment No. 200 I 187 Single Control Rod Withdrawal -Cold Shutdown 3.10.3 3.10 SPECIAL OPERATIONS 3.10.3 Single Control Rod Withdrawal -Cold Shutdown LCO 3.10.3 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. 7.a, 7.b, 10, and 11 of Table 3.3.1.1-1.
LCO 3.3.8.2. "Reactor Protection System (RPS)Electric Power Monitoring," MODE 5 requirements, 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, at which time 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.APPLICABILITY:
MODE 4 with the reactor mode switch in the refuel position.LaSalle 1 and 2 3.10.3-1 Amendment No. 147/133 Single Control Rod Withdrawal -Cold Shutdown 3.10.3 ACTIONS-------------------------------------
NOTE-------------------------------------
Separate Condition entry is allowed for each requirement of the LCO.CONDITION I REQUIRED ACTION I 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__________________________________
I I (continued)
LaSalle 1 and 2 3.10.3-2 Amendment No. 147/133 Single Control Rod Withdrawal-Cold Shutdown 3.10.3 CONDITION REQU I RED ACTI ON COMPLETION TIME B. One or more of the B.1 Suspend withdrawal of Immediately above requirements not the control rod and met with the affected removal of associated control rod not CRD. insertable.
B.2.1 Initiate action to fully insert all control rods. Immediately B.2.2 Initiate action to satisfy the requirements of this LCO. Immediately SURVEILLANCE SR 3.10.3.1 SURVEILLANCE Perform the applicable SRs required LCOs. for the FREQUENCY According to applicable SRs SR 3.10.3.2 -Not required to be met if SR satisfied for LCO 3.10.3.c.1 requirements.
3.10.3.1 is Verify all control rods. other than the control rod being withdrawn.
in a five by fi ve array centered on the control rod being withdrawn, are disarmed.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.10.3-3 Amendment No.200 ! 187 Single Control Rod Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SR 3.10.3.3 SURVEILLANCE Veri fy all control rods, other than the control rod being withdrawn, are fully inserted.
FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.10.3.4 Not required to be met if SR 3.10.3.1 satisfied for LCO 3.10.3.b.1 requirements.
is Verify a control inserted.
rod withdrawal block is In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.3 4 Amendment No.2DD / 187 Single CRD Removal -Refueling 3.10.4 3.10 SPECIAL OPERATIONS 3.10.4 Single Control Rod Drive (CRD) Removal -Refueling LCO 3.10.4 The requirements of LCO 3.3.1.1. "Reactor Protection System (RPS) Instrumentation";
LCO 3.3.8.2. "Reactor Protection System (RPS).Electric Power Monitoring";
LCO 3.9.1,"Refueling Equipment Interlocks";
LCO 3.9.2. 'Refuel Position One-Rod-Out Interlock":
LCO 3.9.4. "Control Rod Position Indication";
and LCO 3.9.5. "Control Rod OPERABILITY -Refueling." may be suspended in MODE 5 to allow the removal of a single CRD associated with a control rod withdrawn from a core cell containing one or more fuel assemblies, provided the following requirements are met: a. All other control rods are fully inserted;b. All other control rods in a five by five array centered on the withdrawn control rod are disarmed;c. A control rod withdrawal block is inserted, and LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 5 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod; and d. No other CORE ALTERATIONS are in progress.APPLICABILITY:
MODE 5 with LCO 3.9.5 not met.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend removal of Immediately above requirements not the CRD mechanism.
met.AND (continued)
LaSalle I and 2 3.10.4-1 Amendment No. 147/133 Single CRD Removal-Refueling 3.10.4 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. (continued)
A.2.1 Initiate action to fully insert all control rods. Immediately A.2.2 Initiate action to satisfy the requirements of this LCO. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.10.4.1 Verify all controls rods, other than the control rod withdrawn for the removal of the associated CRD, are fully inserted.
In accordance with the Surveillance Frequency Control Program SR 3.10.4.2 Verify all control rods, other than the control rod withdrawn for the removal of the associated (RD, in a five by five array centered on the control rod withdrawn for the removal of the associated CRD, are disarmed.
In accordance with the Surveillance Frequency Control Program SR 3.10.4.3 Verify a control rod withdrawal block is inserted.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.10.4-2 Amendment No. 200/ 187 Single CRD Removal-Refueling 3.10.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.4.5 Verify no other CORE ALTERATIONS are in progress.
In accordance with the Surveillance Frequency Control Program LaSall eland 2 3.10.4-3 Amendment No. 200/ 187 Multiple Control Rod Withdrawal -Refueling 3.10.5 3.10 SPECIAL OPERATIONS 3.10.5 Multiple Control Rod Withdrawal -Refueling LCO 3.10.5 The requirements of 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 not be loaded into or shuffled within the reactor pressure vessel.APPLICABILITY:
MODE 5 with LCO 3.9.4 or LCO 3.9.5 not met.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend withdrawal of Immediately above requirements not control rods and met. removal of associated CRDs.AND A.2.1 Initiate action to Immediately fully insert all control rods in core cells containing one or more fuel assemblies.
OR (continued)
La~alle 1 and 2 3.10.5-1 Amendment No. 147/133 Multiple Control Rod Withdrawal-Refueling 3.10.5 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. (continued)
A.2.2 Initiate action to satisfy the requirements of this LCO. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify the four fuel assemblies are removed from core cells associated with each control rod or CRD removed. In accordance with the Surveillance Frequency Control Program SR 3.10.5.2 Verify all other control rods in core cells containing one or more fuel assemblies are fully inserted.
In accordance with the Surveillance Frequency Control Program SR 3.10.5.3 Verify fuel assemblies are not being loaded into or shuffled within the reactor pressure vessel. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.5 2 Amendment No. 200 / 187 Control Rod Testing -Operating 3.10.6 3.10 SPECIAL OPERATIONS 3.10.6 Control Rod Testing -Operating LCO 3.10.6 The requirements of LCO 3.1.6. "Rod Pattern Control," may be suspended to allow performance of SOM demonstrations, control rod scram time testing, and control rod friction testing provided: a. The analyzed rod position sequence requirements of SR 3.3.2.1.8 are changed to require the control rod sequence to conform to the specified test sequence.OR b. The RWM is bypassed; the requirements of LCO 3.3.2.1.'Control Rod Block Instrumentation." Function 2 are suspended; and 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 REOUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Suspend performance Immediately LCO not met. of the test and exception to LCO 3.1.6.LaSalle 1 and 2 3.10.6-1 Amendment No. 147/133 Control Rod Testing -Operating 3.10.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1-------------------
NOTE--------------------
Not required to be met if SR 3.10.6.2 satisfied.
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 SR 3.10.6.2-------------------
NOTE--------------------
Not required to be met if SR 3.10.6.1 satisfied.
Verify control rod sequence input to the RWM is in conformance with the approved control rod sequence for the specified test.Prior to control rod movement LaSalle 1 and 2 3.10.6- 2 Amendment No. 147/133 SDM Test -Refueling 3.10.7 3.10 SPECIAL OPERATIONS 3.10.7 SHUTDOWN MARGIN (SDM) Test -Refueling LCO 3.10.7 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 (RPS)Instrumentation," MODE 2 requirements for Functions 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 2 of Table 3.3.2.1-1.
with the analyzed rod position sequence requirements of SR 3.3.2.1.8 changed to require the control rod sequence to conform to the SDM test sequencing, 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 > 940 psig.APPLICABILITY:
MODE 5 with the reactor mode switch in startup/hot standby position.LaSalle 1 and 2 3.10.7 -1 Amendment No. 147/133 SDM Test- Refueling 3.10.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME---- -NOTE --------------
NOTE-------------
Separate Condition entry Rod Worth Minimizer may be is allowed for each bypassed as allowed by control rod. LCO 3.3.2.1, if required, to allow insertion of inoperable control rod and continued A. One or more control operation.
rods not coupled to its associated CRD.A.1 Fully insert 3 hours inoperable control rod.AND A.2 Disarm the associated 4 hours CRD.B. One or more of the B.1 Place the reactor Immediately above requirements not mode switch in the met for reasons other shutdown or refuel than Condition A. position.SURVEILLANCE REQUIREMENTS
.SURVEILLANCE FREQUENCY SR 3.10.7.1 Perform the MODE 2 applicable SRs for LCO According to 3.3.1.1. Functions 2.a and 2.d of Table the applicable 3.3.1.1-1.
SRs (continued)
LaSalle I and 2 3.10.7-2 Amendment No. 147/133 SDM Test-Refueling 3.10.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.2 --NOTE Not required to be met if SR 3.10.7.3 satisfied.
Perform the MODE 2 applicable SRs for LCO 3.3.2.1, Function 2 of Table 3.3.2.1 1. According to the applicable SRs SR 3.10.7.3 NOTE Not required to be met if SR 3.10.7.2 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 3.10.7.4 Verify no other CORE ALTERATIONS are in progress.
In accordance with the Surveillance Frequency Control Program (continued)
LaSalle 1 and 2 3.10.7-3 Amendment No. 200 / 187 SOM Test-Refueling 3.10.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.5 Verify each withdrawn control rod does not go to the withdrawn overtravel position.
Each time the control rod is withd rawn to "full out" position Prior to satisfying LCO 3.10.7.c requirement after work on contra 1 rod or CRD System that could affect coupling SR 3.10.7.6 Verify CRD charging water header pressure 940 psig. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.7-4 Amendment NO.200 / 187 Inservice Leak and Hydrostatic Testing Operation 3.10.8 3.10 SPECIAL OPERATIONS 3.10.8 Inservice Leak and Hydrostatic Testing Operation LCO 3.10.8 APPLICABILITY:
LaSalle 1 and 2 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&deg;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)," d. LCO 3.6.4.3, "Standby Gas Treatment (SGT) System." MODE 4 with average reactor coolant temperature>
200&deg;F. 3.10.8-1 Amendment No. 219/ 205 Inservice Leak and Hydrostatic Testing Operation 3.10.8 ACTIONS -------------------------------------NOTE -------------------------------------Separate Condition entry is allowed for each requirement of the LCO. CONDITION A. One or more of the A.l above requirements not met. A. 2 .1 A.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE REQUIRED ACTION Required Actions to be in MODE 4 include reducing average reactor coolant temperature to 200&deg;F. Enter the applicable Condition of the affected LCO. Suspend activities that could increase the average reactor coolant temperature or pressure.
Reduce average reactor coolant temperature to 200&deg;F. SR 3.10.8.1 Perform the applicable SRs for the required MODE 3 LCOs. COMPLETION TIME Immediately Immediately 24 hours FREQUENCY According to the applicable S Rs LaSalle 1 and 2 3.10.8-2 Amendment No.219 I 205 Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location 4.1.1 Site and Exclusion Area Boundaries The site area and exclusion area boundaries are as shown in Figure 4.1-1.4.1.2 Low Population Zone The low population zone is all the land within a circle with its center at the vent stack and a radius of 3.98 miles.4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 764 fuel assemblies.
Each assembly shall consist of a matrix of Zircaloy clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UD 2) as fuel material, and water rods or water boxes.Limited substitutions of Zircaloy.
ZIRLO, 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 185 cruciform shaped control rod assemblies.
The control material shall be boron carbide and hafnium metal as approved by the NRC.(continued)
LaSalle 1 and 2 4.0-1 Amendment No. 147/133 Design Features 4.0 4.0 DESIGN FEATURES (continued)
: 4. 3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with: LaSalle 1 and 2 a. kett ::s; 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in either: (1) Section 9.1.2 of the UFSAR, or (2) AREVA NP Inc. Report No. ANP-2843(P), "LaSalle Unit 2 Nuclear Power Station Spent Fuel Storage Pool Criticality Safety Analysis with Neutron Absorbing Inserts and Without Borafl ex," Revision 1, dated August 2009, for the Unit 2 spent fuel storage racks with rack inserts. b. A nominal 6.26 inch center to center distance between fuel assemblies placed in the storage racks. c. For Unit 2 only, spent fuel shall only be stored in storage rack cells containing a neutron absorbing rack insert. The neutron absorbing rack inserts shall have a minimum certified 10 8 areal density greater than or equal to 0.0086 grams 10 B/cm 2* The approved inserts are those described in Attachment 4 to the letter from P. Simpson to the NRC, dated October 5, 2009. d. The combination of U-235 enrichment and gadolinia loading shall be limited to ensure fuel assemblies have a maximum k-infinity of 0.9185 for all lattices in the top of the assembly, a maximum k-infinity of 0.8869 for all lattices in the intermediate portion of the assembly, and a maximum k-infinity of 0.8843 for all lattices in the bottom of the assembly as determined at 4&deg;C in the normal spent fuel pool in-rack configuration.
The bottom, intermediate, and top zones are between 0"-96", 96"-126", and greater than 126" above the bottom of the active fuel. (continued) 4.0-2 Amendment No. 207 ;194 Design Features 4.0 DESIGN FEATURES 4.3.1 Criticality (continued) For Unit 2 only, at the interface between a non-insert rack module and an insert rack module of the spent fuel pool, the placement of inserts will be expanded one row and one column into the non-insert rack module as necessary to completely surround all assemblies in the insert rack module with four wings of an insert. 4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 819 ft. 4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 3986 fuel assemblies for Unit 1 and 4078 fuel assemblies for Unit 2. LaSalle 1 and 4.0-3 Amendment No. 199/186 
-------4.0 Design Features l..iquid Effluent I 20,00
* 40.00 "lute Sla!:oili%alion Pond Exclusion I I
__I 1 Mile Scale in Feel Sit.e Boundery (Property Une) laSalle Lake IStation I Sleck I I L. _____ J Figure 4.1-1 (Page 1 of 1) Site and Exclusion Area Boundaries LaSalle 1 and 2 4.0-4 Amendment No. 199/186 Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The station manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.5.1.2 A unit supervisor shall be responsible for the control room command function (Since the control room is common to both units.the control room command function for both units can be satisfied by a single unit supervisor).
During any absence of the unit supervisor 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 unit supervisor from the control room while the unit is in MODE 4 or 5 or defueled, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.LaSalle I and 2 5.1-1 Amendment No. 147/133 Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Oraanizations K Onsite and offsite organizations shall be established for unit operation-and corporate--management,;
respectivel-y.-
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 generic titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications, shall be documented in the Quality Assurance Manual.b. The station 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 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.d. The individuals who train the operating staff, or perform radiation protection or 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.
Unit Staff..The unit. staff organization shall include the following:
5.2.2 a. of three'required in all c(La SaIIe. l and '2'* ,;} ; " non-licensed operators for the two units is)nditions.
At least one of the required (continued) 5.2-1 Amendment No. 187/174 Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) non-l icensed operators shall be assigned to each unit. b. Shift crew composition may be less than the mlnlmum requirement of 10 CFR 50.54(ml(2)(i) and Specifications 5.2.2.a and 5.Z.2.e for a period of time not to exceed 2 hours in order to accommodate unexpected absence of 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 shift operations supervisor shall hold an SRO license. e. The Shift Technical Advisor (STAl shall provide advisory technical support to the shift manager in the areas of thermal hydrau1ics, reactor engineering, and plant analysis with regard to the safe operation of the unit. In addition, the STA shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Sh i ft. LaSalle 1 and 2 Amendment No. 192/179 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications Unit Staff Qualifications
: 5. 3 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI N18.1-1971, with the following exceptions:
ll the r*ac!iation protection manager shall meet the requirements of ''radiation protection manager''
in Regulatory Guide 1.8, September 1975, and 2) the licensed operators who shall comply only with the requirements of 10 CFR 55. Also, the ANSI N18.1-1971 qualification requirements for "radiation protection technician" may be met by either of the following alternatives:
: a. Individuals who have completed the radiation protection technician training program and have accrued one year of working experience in the specialty; or b. Individuals who have completed the radiation protection technician training program, but have not yet accrued one year of working experience in the specialty, who are supervised by on*shift radiation protection supervision who meet the requirements of ANSI NlB.l-1971, Section 4.3.2 or Section 4.4.4. LaSalle I and 2 5.3-1 Amendment No. 206/193 Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented.
and maintained covering the following activities:
: a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A. February 1978;b. The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737, Supplement 1, as stated in Generic Letter 82-33, Section 7.1;c. Fire Protection Program implementation:
and d. All programs specified in Specification 5.5.LaSalle 1 and 2 5.4 -1 Amendment No. 147/133 Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.
5.5.1 Offsite Dose Calculation Manual (ODCM)a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Reports required by Specification 5.6.2 and Specification 5.6.3.c. Licensee initiated changes to the ODCM: 1. Shall be documented and records of reviews performed shall be retained.
This documentation shall contain: (a) Sufficient information to support the change(s)together with the appropriate analyses or evaluations justifying the change(s), and (b) 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 do not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations:
: 2. Shall become effective after the approval of the station manager; and 3. 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.(continued)
La~alle I and 2 5.5-1 Amendment No. 147/133 Programs and Manuals 5.5 5.5 Programs and Manuals.5.5.1 Offsite Dose Calculation Manual (ODCM) (continued)
Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.
5.5.2 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/Low Pressure Coolant Injection, Reactor Core Isolation Cooling, containment monitoring, Standby Gas Treatment, hydrogen recombiner and process sampling (until such time as a modification eliminates the hydrogen recombiner and PASS penetrations as potential leakage paths). The program shall include the following:
: a. Preventive maintenance and periodic visual inspection requirements; and b. Integrated leak test requirements for each system at 24 month intervals.
The provisions of SR 3.0.2 are applicable to the 24 month Frequency for performing integrated system leak test activities.
5.5.3 Deleted.(continued)
LaSalle I and 2 5.5-2 Amendment No. / 172/158 Programs and Manuals 5.5 Programs and Manuals 5.5.4 Radioactive Effluen.L Controls Pr'ogr-lli!! 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: Limitations on the functional capability of radioactive liqUid and gaseous monitoring instrumentation including surveil lance tests and setpoint determination in accordance with the methodology in the ODCM; 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; 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 aDeM; 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; 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 aDCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the aDeM at least every 31 days; 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; Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to (continued)
LaSalle 1 and S.5-3 Amendment No. 190 and 177 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued) areas at or beyond the site boundary shall be in accordance with the following:
: 1. For noble gases: a dose rate < 500 mrems/yr to the whole body and a dose rate < 3000 mrems/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 mrems/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;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; and k. Limitations on venting and purging of the primary containment through the Primary Containment Vent and Purge System or Standby Gas Treatment System to maintain releases as low as reasonably achievable.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluents Control Program Surveillance Frequencies.
5.5.5 Component Cyclic or Transient Limit This program provides controls to track the UFSAR. Table 5.2-4, cyclic and transient occurrences to ensure that components are maintained within the design limits.(continued)
LaSalle I and 2 5.5 -4 Amendment No. 147/133 Programs and Manuals 5.5 5 5.5 Programs and Manuals 5.5.6 Inservire Insnection Proaram for Post Tensionina Tendons This program provides controls for monitoring any tendon degradation in pre-stressed concrete containments, including effectiveness of its corrosion protection medium, to ensure containment structural integrity.
The program shall include baseline measurements prior to initial operations.
The Tendon Surveillance Program, inspection frequencies, and acceptance criteria shall be in accordance with Section XI, Subsection IWL of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR 50.55a as amended by relief granted in accordance with 10 CFR 50.55a(a)(3).
The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies.
Inservice Testina Proaram 5.5.7 This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 pumps and valves.a. Testing Frequencies applicable to the ASME Code for Operation and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda are as follows: ASME OM Code and applicable Addenda terminology for inservice testing activities Weekly Monthly Quarterly or every 3 months Semiannually or every 6 months Every 9 months Yearly or annually Biennially or every 2 years Every 48 months I Required Frequencies for performing inservice testing activities At least once per 7 days At least once per 31 days At least once per 92 days At At At least 1 east least once once once per 184 days per 276 days per 366 days At least once per 731 days At least once per 1461 days (continued)
LaSalle 1 and 2 5.5-5 Amendment Nov.185/172 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Inservice Testing Proaram (continued)
: 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)The VFTP shall establish the required testing of Engineered Safety Feature (ESF) filter ventilation systems. Tests described in Specification 5.5.8.a and 5.5.8.b shall be performed once per 24 months; after each complete or partial replacement of the HEPA filter bank or charcoal adsorber bank; after any structural maintenance on the HEPA filter bank or charcoal adsorber bank housing; and, following painting, fire, or chemical release in any ventilation zone communicating with the subsystem while it is in operation that could adversely affect the filter bank or charcoal adsorber capability.
Tests described in Specification 5.5.8.c shall be performed once per 24 months; after 720 hours of system operation; after any structural maintenance on the charcoal adsorber bank housing; and, following painting, fire, or chemical release in any ventilation zone communicating with the subsystem while it is in operation that could adversely affect the charcoal adsorber capability.
Tests described in Specification 5.5.8.d and 5.5.8.e shall be performed once per 24 months.The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
: 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 ANSI/ASME N510-1989 at the system flowrate specified below: (continued)
LaSalle I and 2 5.5-6 Amendment No.185/172
-Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Ventilation Filter Testing Program (VFTP) (continued)
ESF Ventilation System Flowrate (cfm)Standby Gas Treatment (SGT) System Control Room Area Filtration (CRAF)System Emergency Makeup Air Filter Units (EMUs)> 3600 and < 4400> 3600 and < 4400 b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass less than the value specified below when tested in accordance with ANSI/ASME N510-1989 at the system flowrate specified below: ESF Ventilation System Penetration and System BvDass Flowrate (cfm)SGT System 0.05%> 3600 and < 4400 CRAF System EMUs 0.05%Control Room Recirculation Filters (CRRFs)Auxiliary Electric Equipment Room Reci rcul ati on Filters (AEERRFs)2.0%2.0%2 3600 and < 4400> 18000 and < 28900> 14000 and < 22800 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 0 C, a relative humidity of 70%, and a face velocity as specified below: (continued)
LaSalle 1 and 2 5. 5- 7 Amendment No. 147/133 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Ventilation Filter Testing Program (VFTP) (continued)
ESF Ventilation Svstem Penetration Face Velocity (fpm)SGT System 0.5%40 CRAF System EMUs CRRFs AEERRFs 2.5%15.0%15.0%40 80 80 d. Demonstrate for each of the ESF systems that the pressure drop across the combined moisture separator, heater, HEPA filters. prefilters, and charcoal adsorbers is less than the value specified below when tested at the system flowrate specified below: ESF Ventilation System Delta P (inches WG)Flowrate (cfm)SGT System 8> 3600 and < 4400 CRAF System EMUs 8 CRRFs 3.0> 3600 and < 4400> 18000 and < 28900> 14000 and < 22800 AEERRFs 3.0 (continued)
LaSalle I and 2 5.5-8 Amendment No. 147/133 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Ventilation Filter Testing Program (VFTP) (continued)
: e. Demonstrate that the heaters for each of the ESF systems dissipate the value specified below, corrected for voltage variations at the 480 V bus, when tested in accordance with ANSI/ASME N510-1989:
ESF Ventilation System Wattage (kW)SGT System > 21 and < 25 CRAF System EMUs > 18 and < 22 5.5.9 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Condenser Offgas Treatment System and the quantity of radioactivity contained in any outside temporary tanks.The program shall include: a. The limits for concentrations of hydrogen in the Condenser Offgas Treatment 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);
and b. A surveillance program to ensure that the quantity of radioactivity contained in all outside temporary 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 Waste Management Systems is less than or equal to the amount that would result in concentrations less than the limits specified in the ODCM, 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.(continued)
LaSalle 1 and 2 5.5-9 Amendment No. 147/133 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Diesel Fuel Oil Testing Program A diesel fuel oil testing program shall establish the required testing of both new fuel oil and stored fuel oil. 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.3. A clear and bright appearance with proper color or water and sediment 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; and c. Total particulate concentration of the fuel oil in the storage tanks is < 10 mg/l when tested every 31 days in accordance with the applicable ASTM Standard.The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test frequencies.
5.5.11 Technical SDecifications (TS) Bases Control Proaram 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 (continued)
'LaSalle I and 2 5.5 -1 0 Amendment No. 147/133.
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Technical SDecifications (TS) Bases Control Program (continued)
: 2. A change to the UFSAR 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 UFSAR.d. Proposed changes that meet the criterion of Specification 5.5.11.b.1 or 5.5.11.b.2 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.a. The SFDP shall contain the following:
: 1. 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:
: 2. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists: 3. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and 4. Other appropriate limitations and remedial or compensatory actions.(continued)
LaSalle 1 and 2 5. 5-11 Amendment No. 147/133 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Safetv Function Determination Program (SFDP) (continued)
: b. A loss of safety function exists when, assuming no concurrent single failure, and assuming no concurrent loss of offsite power or 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: 1. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or 2. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or 3. A required system redundant to support system(s) for the supported systems described in b.1 and b.2 above is also inoperable.
K c. 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 Primarv Containment Leakaae Rate Testing Program a. This program shall establish the leakage rate testing of the primary containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix, J, Option B, as modified by approved exemptions.
This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163,"Performance-Based Containment Leak-Testing Program," dated September 1995 as modified by the following exceptions:
: 1. NEI 94-01 -1995, Section 9.2.3: The first Unit 1 Type A test performed after June 14, 1994 Type A test shall be performed no later than June 13, 2009.(continued)
LaSalle 1 and 2 5.5 -12 Amendment No 1.6 154 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Primarv Containment Leakage Rate Testing Program (continued)
: 2. NEI 94-01 -1995, Section 9.2.3: The first Unit 2 Type A test performed after December 8, 1993 Type A test shall be performed prior to startup following L2R12. 3. The potential valve atmospheric leakage paths that are not exposed to reverse direction test pressure shall be tested during the regularly scheduled Type A test. The program shall contain the list of the potential valve atmospheric leakage paths, leakage rate measurement method, and acceptance criteria.
This exception shall be applicable only to valves that are not isolable from the primary containment free air space. b. The peak calculated primary containment internal pressure for the design basis loss of coolant accident, P,, is 42.6 psig. c. The maximum allowable primary containment leakage rate, L,, at P,, is 1.0% of primary containment air weight per day. d. Leakage rate acceptance criteria are: 1. Primary containment overall leakage rate acceptance criterion 1.0 L,. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria 0.60 L, for the combined Type Band Type C tests, 0.75 L, for Type A tests. 2. Air lock testing acceptance criteria are: a) Overall air lock leakage rate 0.05 L, when tested at P,. b) For each door, the seal leakage rate is 5 scf per hour when the gap between the door seals is pressurized 10 psig. e. The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program. (continued)
LaSalle 1 and 2 5.5-13 Amendment No. 212/198 Programs and Manuals 5.5 Programs and Manuals 5.5.14 Battery Monitoring and Maintenance Program This Program provides for restoration and maintenance, which includes the following: Actions to restore battery cells with float voltage < 2.13 V; and Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the pl ates; and Actions to verify that the remalnlng cells are  2.07 V when a cell or cells have been found to be
< 2.13 V. 5.5.15 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Area Filtration (CRAF) System, eRE 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, or 5 rem TEDE, as applicable. The program shall include the following elements: The definition of the CRE and the CRE boundary. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance. Requi rements for (i) determi ni ng the unfi 1 tered ai r 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 O. (continued)
LaSalle 1 and 5.5-14 Amendment No. 197/184 Programs and Manuals 5.5 Programs and Manuals 5.5.15 Control Room Envelope Habitability Program (continued) Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CRAF System, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 24 month assessment of the CRE boundary. 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 inleakge limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.
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. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program. (continued) 5.5.16 LaSalle 1 and 5.5 15 Amendment No. 200 / 187 Programs and Manuals 5.5 Programs and Manuals 5.5.16 Surveillance Frequency Control Program (continued) Changes to the "requencies 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. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program. LaSalle 1 and 5.5-16 Amendment NO*200 / 187 Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.5.6.1 5.6.2 (Deleted)Annual Radiological Environmental Operatina Renort-------------------
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 (continued)
LaSalle 1 and 2 5.6-1I Amendment No. 173,159 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radioloaical Environmental Operating Report (continued)(ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.5.6.3 Radioactive Effluent Release Report-------------------------------
NOTE------------
...A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.The Radioactive Effluent Release Report covering the operation of the unit 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 the Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.5.6.4 (Deleted)5.6.5 CORE OPERATING LIMITS REPORT (COLR)a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:
: 1. The APLHGR for Specification 3.2.1.2. The MCPR for Specification 3.2.2.3. The LHGR for Specification 3.2.3.(continued)
LaSalle 1 and 2 5.6 -2 Amendment No. 173,159 Reporting Requirements 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued) The Rod Block Monitor Upscale Instrumentation Setpoint for the Rod Block Monitor-Upscale Function Allowable Value for Specification 3.3.2.1. The OPRM setpoints for the trip function for SR 3.3.1.3.3. 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: ANF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors." ANF-913(P)(A), "COTRANSA 2: A Computer Program for Boiling Water Reactor Transient Analysis." MF-CC-33(P)(A), "HUXY: A Generalized Il1ultirod Heatup Code with 10 CFR 50, Appendix K Heatup Option." XN-NF-80-19(P)(A), "Advanced Nuclear Fuel Methodology for Boiling Water Reactors." XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Jet Pump BWR Reload Fuel." EMF-CC-074(P)(A), Volume 4 -"BWR Stability Analysis:
Assessment of STAIF with input from MICROBURN-B2." XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model." XN-NF-84-105(P)(A), "XCOBRA-T:
A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis." (continued)
LaSalle 1 and 2 Amendment No. 194/181 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)
: 9. EMF-2209(P)(A), "SPCB Critical Power Correlation." 10. ANF-89-98(P)(A), "Generic Mechanical Design Criteria for BWR Fuel Designs." 11. NEDE-24011-P-A, "General Electric Standard Application for Reactor Fuel." 12. NFSR-0091, "Benchmark of CASMO/MICROBURN BWR Nuclear Design Methods." 13. EMF-85-74(P)(A), "RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model." 14. EMF-2158(P)(A), "Siemens Power Corporation Methodology for Boiling Water Reactors:
Evaluation and Validation of CASMO-4/MICROBURN-B2." 15. NEDC-33106P, "GEXL97 Correlation for Atrium-i0 Fuel." 16. EMF-2245(P)(A), "Application of Siemens Power Corporation's Critical Power Correlations to Co-Resident Fuel." 17. EMF-2361(P)(A), "EXEM BWR-2000 ECCS Evaluation Model." 18. NEDO-32465-A, "BWR Owners' Group Reactor Stability Detect and Suppress Solutions Licensing Basis Methodology and Reload Applications," August 1996.19. ANF-1358(P)(A), "The Loss of Feedwater Heating Transient in Boiling Water Reactors." (continued)
LaSalle 1 and 2 5.6-4 Amendment No.1 8 1/1 6 8 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIM1IS REPORT (COLR) (continued)
The COLR will contain the complete identification for each of the TS referenced topical reports used to prepare the COLR (i.e., report number, title, revision, date, and any supplements).
: 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.5.6.6 Post Accident Monitoring (PAM) Instrumentation Report When a 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.LaSalle I and 2 5.6-5 Amendment No. 177/163 High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20: 5.7.1 Hiah Radiation Areas with Dose Rates Not Exceedino 1.0 remlhour 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 (continued)
LaSalle 1 and 2 5.7 -1 Amendment No.161/147 High Radiation Area 5.7 5.7 High Radiation Area 5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation (continued)
: 4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure with the area, or (ii) Be under the surveillance, as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.
: e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.5.7.2 Hiah Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at i 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 (continued)
LaSalle 1 and 2 5.7-2 Amendment No.161/147 High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued) 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.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 (continued), LaSalle 1 and 2 5.7-3 Amendment No. 161/147 High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued)
: 3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, Ci) 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 (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.(continued)
LaSalle I and 2 5.7-4 Amendment No.161/147.
High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 remihour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation.
but less than 500 rads/hour at I 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.LaSalle I and 2 5. 7- 5 Amendment No. 161/147 1'PO No Fz 'rom, LICEISELUMhOMIlY FILL COIPY APPENDIX B TO FACILITY LICENSE NOS. NPF-11 AND NPF-18 LASALLE COUNTY STATION UNITS 1 AND 2 I EXELON GENERATION COMPANY, LLC DOCKET NOS. 50-373 AND 50-374 ENVIRONMENTAL PROTECTION PLAN Amendment No. 132 JAN 1 2 2001 LA SALLE COUNTY STATION UNITS 1 AND 2 ENVIRONMENTAL PROTECTION PLAN (NON-RADIOLOGICAL)
TABLE OF CONTENTS 7.-,  i I I II.I I I I I I I i I Section 1.0 Objectives of the Environmental Protection 2.0 Environmental Protection Issues. .....2.1 Aquatic Issues ..............2.2 Terrestrial Issues ............3.0 Consistency Requirements
.........3.1 Plant Design and Operation
........3.2 Reporting Related to the NPDES Permits and Certification.
..............3.3 Changes Required for Compliance with Other Regulation
.............. ...4.0 Environmental Conditions
.........4.1 Unusual or Important Environmental Events.4.2 Environmental Monitoring
.........5.0 Administrative Procedures.
........5.1 Review and Audit .............5.2 Records Retention.
............5.3 Changes in Environmental Protection Plan .5.4 Plant Reporting Requirements
.......Plan.Page..1-1 2-1..2-1..2-2..3-1..3-1..3-2...State.....r.et Environmental
.........3-3.........4-1.........4-1.........4-1.........5-1.........5-1.........5-1.........5-1.........5-2 1.0 OBJECTIVE OF THE ENVIRONMENTAL PROTECTION PLAN The Environmental Protection Plan (EPP) provides for protection of environmental values during operation of the nuclear facility.
The principal objectives of the EPP are as follows: (1) Verify that the Plant is operated in an e nvironmentally acceptable manner, as established by the FES and other NRC environm ental impact assessments.
(2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.
(3) Keep NRC informed of the environmental effects of facility operation and of action taken to control those effects.Environmental concerns identified in the FES which relate to water quality matters are regulated by way of the licensee's NP DES permit.1-1 Amendment No. 176/162 2.0 ENVIRONMENTAL PROTECTION ISSUES In the FES-OL dated November 1978, the staff considered the environmental impacts associated with the operation of the two-unit La Salle County Station.Certain environmental issues were identified which required study or license conditions to resolve environmental concerns and to assure adequate protection of the environment.
2.1 Aquatic Issues Specific aquatic issues raised by the staff in the FES-OL were: (1) The need for aquatic monitoring programs to confirm that thermal mixing results in compliance with State water quality standards as predicted, that chlorine releases are controlled within those discharge concentra-tions evaluated, and that effects on aquatic biota and water quality due to plant operation are no greater than predicted.
(2) The need for special studies to document levels of intake entrainment and impingement.
(3) The need for a special study to document the levels of indicator organisms in the cooling lake for the purpose of identifying and defining the presence of potential public health hazard.(FES-OL: Summary and Conclusions and Sections 6.2 and 6.3)2-1 Aquatic issues identified in items 1 and 2 above are addressed by the effluent limitations, monitoring requirements and the Section 316(b) demonstration requirement contained in the effective NPDES permit issued by the Federal or State permitting authority.
The NRC will rely on these agencies for regulation of these matters as they involve water quality and aquatic biota. The aquatic issue identified in item 3 above has been addressed in correspondence between the NRC and the State of Illinois.
The State has been appraised of the intention of the NRC not to include this monitoring and mitigation requirements in this facility license. The NRC will rely on the State of Illinois for the establishment and conduct of this program. This action has been taken in accordance with Section 511 (c)(2) of the Clean Water Act which places responsibility for establishment and enforcement of programs for the protection of the aquatic environment with the U.S. Environmental Protection Agency or State(s) granted authority for such programs under the Act.2.2 Terrestrial Issues Potential erosion effects along the dike around the cooling lake and the banks of Armstrong Run are addressed in the regulatory requirements of the dam permit issued by the State permitting authority.
The NRC will rely on this State agency for regulation of these matters.2-2 Amendment No. 176/162 3.0 CONSISTENCY REQUIREMENTS 3.1 Plant Design and Operation The licensee may make changes in plant design or operation or perform tests or experiments affecting the environment provided such changes, tests or experi-ments do not involve an unreviewed environmental question, and do not involve a change in the Environmental Protection Plan.* Changes in plant design or operation and performance of tests or experiments which do not affect the environment are not subject to the requirements of this EPP. Activities governed by Section 3.3 are not subject to the requirements of this section.Before engaging in additional construction or operational activities which may affect the environment, the licensee shall prepare and record an environmental evaluation of such activity.**
When the evaluation indicates that such activity involves an unreviewed environmental question, the licensee shall provide a written evaluation of such activities and obtain prior approval from the Director, Office of Nuclear Reactor Regulation.
When such activity involves a change in the Environmental Protection Plan, such activity and change to the Environmental Protection Plan may be implemented only in accordance with an appropriate license amendment as set forth in Section 5.3.This provision does not relieve the licensee of the requirements of 10 CFR 50.59.**Activities are excluded from this requirement if all measurable environmental effects are confined to on-site areas previously disturbed during site pre-paration and plant construction.
3-1 A proposed change, test or experiment shall be deemed to involve an unreviewed environmental question if it concerns (1) a matter which may result in a significant increase in any adverse environmental impact previously evaluated in the final environmental statement (FES) as modified by staff's testimony to the Atomic Safety and Licensing Board, supplem ents to the FES, environmental impact appraisals, or in any decisions of the Atomic Safety and Licensing Board; or (2) a significant change in effluents or power level or (3) a matter not previously reviewed and evaluated in the documents specified in (1) of this Subsection, which may have a significant adverse environmental impact.The licensee shall maintain records of changes in the plant design or operation and of tests and experiments carried out pursuant to this Subsection.
These records shall include written evaluations which provide bases for the determination that the change, test, or experiment does not involve an unreviewed environmental question nor constitute a decrease in the effectiveness of this EPP to meet the objectives specified in Section 1.0.3.2 Reportina Related to the NPDES Permits and State Certification The licensee shall provide the NRC with copies of the results of the special studies conducted in accordance with the Clean Water Act at the same time they are submitted to the permitting agency, namely, the Demonstration Study pursuant to Section 316(b) of the Clean Water Act.The NRC shall be provided with a copy of the current NPDES permit or State Certification within 30 days of approval.
Changes to the NPIDES permit or State Certification shall be reported to the NRC within 30 days of the date the change is approved.3-2 Amendment No. 176/162 3.3 Chanaes Required for Compliance with Other Environmental Regulations Changes in plant design or operation and performance of tests or experiments that are either regulated or mandated by other Federal, State, or local environmental regulations are not subject to requirements of Section 3.1. However, if any environmental impacts of a change are not evaluated under other Federal, State or local environmental regulations, then those impacts are subject to the requirements of Section 3.1.3-3 Amendment No. 176/162 4.0 ENVIRONMENTAL CONDITIONS 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates or could result in significant environmental impact causally related to station operation shall be recorded and promptly reported to the NRC within 24 hours followed by a written report per Subsection 5.4.2. If an event is reportable under 10 CFR 50.72, then a duplicate immediate report under this subsection is not required.
However, a follow-up written report is required in accordance with Subsection 5.4.2. The following are examples:
excessive bird impaction events, onsite plant or animal disease outbreaks, mortality or unusual occurrence of any species protected by the Endangered Species Act of 1973, fish kills, increase in nuisance organism s or conditions and unanticipated or emergency discharge of waste water or chemical substances.
No routine monitoring programs are required to implement this condition.
4.2 Environmental Monitioring Environmental monitoring programs are conducted in accordance with the guidance and controls of agencies outside of the NRC. The NRC has recognized the Federal or State agencies as the authorities havi ng jurisdiction in Section 2.0 of this EPP. Therefore, no specific environmental monitoring is required by the NRC under this EP P.4.2.1 Vegetative Integrity on Cooling Pond Dike Deleted 4-1 Amendment No. 176/162 5.0 ADMINISTRATIVE PROCEDURES 5.1 Review and Audit The licensee shall provide for review and audit of compliance with the Environmental Protection Plan. The audits shall be conducted independently of the individual or groups responsible for performing the specific activity.
A description of the organization structure utilized to achieve the independent review and audit function and results of the audit activities shall be maintained and made available for inspection.
5.2 Records Retention Records associated with this EPP shall be made and retained in a manner convenient for review and inspection.
These records shall be made available to NRC on request.Records of modifications to plant structures, systems and components determined to potentially affect the continued protection of the environment shall be retained until the date of the termination of the operating license. All other records and data relating to this EPP shall be retained for five years or, where applicable, in accordance w ith the requirements of other agencies.5.3 Chanaes in Environmental Protection Plan Requests for changes in the Environmental Protection Plan shall include an assessment of the environmental impact of the proposed change an d a support justification.
Implementation of such changes in the E PP shall not commence prior to NRC approval of the proposed chan ges in the form of a licensee amendment incorporating the appropriate revision to the Environmental Protection Plan.5-1 Amendment No. 176/162 5.4 Station Reporting Requirements 5.4.1 Routine Reports Deleted 5.4.2 Nonroutine Reports A written report shall be subm itted to the NRC within 30 days of occurrence of an unusual or important environmental event. The report shall (a) describe, analyze, and evaluate the event, including extent and magnitude of these impact and plant operating characteristics, (b) describe the probable cause of the event, (c) indicate the action taken to correct the reported event, (d)indicate the corrective action tak en to preclude repetiiton of the event and to prevent sim ilar occurences involving similar components or systems and (e) indicate the agencies notiflied and their preliminary responses.
Events reportable under this subsection which also require reports to other Federal, State, or local agencies shall be reported in accordance with those reporting requirements in lieu of the requirements of this subsection.
The NRC shall be provided with a copy of each report at the same time it is submitted to the other agency.5-2 Amendment No. 176/162}}

Latest revision as of 20:17, 9 January 2025

License Appendix a and B
ML16259A059
Person / Time
Site: LaSalle  Constellation icon.png
Issue date: 10/19/2016
From: Jeffrey Mitchell
License Renewal Projects Branch 1
To:
Mitchell J
References
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