ML18212A190

Indian Point, Unit 3, Renewed Facility Operating License DPR-64, Technical Specifications, Appendix a

ML18212A190
Person / Time
Site:	Indian Point
Issue date:	09/17/2018
From:	Division of Materials and License Renewal
To:	Entergy Nuclear Indian Point 3, Entergy Nuclear Operations
Burton W, NRR/DMLR 415-6332
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ML18211A584	List: ML18211A578 ML18211A596 ML18212A032 ML18212A181 ML18212A185 ML18212A188 ML18212A190 ML18212A194 ML18212A195 ML18213A114
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APPENDIX A FACILITY OPERATING LICENSE DPR-64 TECHNICAL SPECIFICATIONS AND BASES FOR THE INDIAN POINT 3 NUCLEAR GENERATING STATION UNIT NO. 3 WESTCHESTER COUNTY, NEW YORK ENTERGY NUCLEAR INDIAN POINT 3 1 LLC (ENIP3) AND ENTERGY NUCLEAR OPERATIONS, INC. (ENO) DOCKET NO. 50-286 Date of Issuance:

April .15, 1976 Amendment No. 203 I TABLE OF CONTENTS Facility Operating License No. DPR-64 Appendix A -Technical Specifications 1.0 USE AND APPLICATION

1.2 Logical

Connectors

1.3 Completion

Times 1.4 Frequency

2.0 SAFETY

LIMITS {SLs) 2.1 Safety Limits 2.2 Safety Limit Violations

3.0 LIMITING

CONDITION FOR OPERATION (LCO) APPLICABILITY SURVEILLANCE REQUIREMENT (SR) APPLICABILITY

3.1 REACTIVITY

CONTROL SYSTEMS 3.1.1 Shutdown Margin (SOM) 3.1.2 Core Reactivity

3.1.3 Moderator

Temperature Coefficient (MTC) 3.1.4 Rod Group Alignment Limits 3.1.5 Shutdown Bank Insertion Limits 3.1.6 Control Bank Insertion Limits 3.1.7 Rod Position Indication

3.1.8 PHYSICS

TE'STS Exceptions-MODE 2 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (FQ(Z)) 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (F\) 3.2.3 AXIAL FLUX DIFFERENCE (AFD) 3.2.4 QUADRANT POWER TILT RATIO (QPTR) 3.3 INSTRUMENTATION

3.3.1 Reactor

Protection System (RPS) Instrumentation

3.3.2 Engineered

Safety Feature Actuation System (ESFAS) Instrumentation 3.3.3 Post Accident Monitoring (PAM) Instrumentation

3.3.4 Remote

Shutdown ' 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation

3.3.6 Containment

Purge System and Pressure Relief Line Isolation Instrumentation

3.3.7 Control

Room Ventilation (CRVS) Actuation Instrumentation 3.3.8 Fuel Storage Building Emergency Ventil*ation System (FSBEVS) Actuation Instrumentation (continued)

INDIP.N POINT 3 Amendment 233 Facility Operating License No. DPR-64 Appendix A -Technical Specifications TABLE OF CONTENTS 3.4 3.4.1 3.4.2 3.4.3 3.4.4 3.4.5 3.4.6 J.4.7 3.4.8 3.4.9 3.4.10 3.4.11 3.4.12 3.4.13 3.4.14 3.4.15 3.4.16 3.4.17 3.5 3.5.1 3.5.2 3.5.3 3.5.4 3.6 3.6.1 .3.6.2 3.6.3 3.6.4 3.6.5 3.6.6 3.6.7 3.6.8 3.6.9 3.6.10 REACTOR COOLANT SYSTEM (RCS) RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits RCS Minimum Temperature for Criticality RCS Pressure and Temperature (P/T) Limits RCS Loops -MODES 1. and 2 RCS Loops -MODE 3 RCS Loops -MODE 4 RCS Loops -MODE 5, Loops Fi 11 ed RCS Loops -MODE 5, Loops Not Fi 11 ed

• Pressurizer Pressurizer Safety Valves .Pressurize~

Power Operated Relief Valves (PORVs) Low Temperature Overpressure Protection (LTOP) RCS Operational LEAKAGE RCS Pressure Isolation Valve (PIV) Leakage RCS Leakage Detection Instrumentation RCS Specific Activity Steam Generator (SG) Tube Integrity EMERGENCY CORE COOLING SYSTEMS (ECCS) Accumul c;\tors ECCS-Operating ECCS -Shutdown Refueling Water Storage Tank (RWS!) CONTAINMENT SYSTEMS Containment Containment Air Locks Containment Isolation Valves Containment Pressure Containment Air Temperature Containment Spray System and Containment

• Fan Cooler System Recirculation pH Control System ' Not Used Isolation Valve Seal Water (IVSW) System Weld Channel and Penetration Pressurization System (WC & PPS) (continued)

INDIAN POINT 3 i i Amendment 236 Facility Operating License No. DPR-64 Appendix A -Technical Specifications TABLE OF CONTENTS 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 3.7.9 3. 7 .10 3. 7 .11 3. 7. 12 3.7.13 3. 7. 14 3. 7. 15 3. 7. 16 3. 7. 17 3.8 3 .8.1 3.8.2 3.8.3 3.8.4 3.6.5 3.8.6 3.8.7 3.8.8 3.8.9 3.8.10 3.9 3. 9. 1 3.9.2 3.9.3 3.9.4 3.9.5 3.9.6 PLANT SYSTEMS Main Steam Safety Valves (MSSVs) Main Steam Isolation Valves (MSIVs) and Main Steam Check Valves (MSCVs) Main Boiler Feedpump Discharge Valves (MBFPDVs), Main Feedwater Regulation Valves (MFRVs), Main Feedwater Inlet Isolation Valves (MFIIVs) and Main Feedwater (MF) Low Flow Bypass Valves Atmospheric Dump Valves (ADVs) Auxiliary Feedwater (AFW) System Condensate Storage Tank (CST) City Water (CW) Component Cooling Water (CCW) System Service Water (SW) System Ultimate Heat Sink (UHS) Control Room Ventilation System (CRVS) Control Room Air Conditioning System (CRACS) Fuel Storage Building Emergency Ventilation System (FSBEVS) Spent Fuel Pit Water Level Spent Fuel Pit Boron Concentration Spent Fuel Assembly Storage Secondary Specific Activity ELECTRICAL POWER SYSTEMS AC Sources-Operating AC Sources -Shutdown Diesel Fuel Oil and Starting Air DC Sources-Operating DC Sources-Shutdown Battery Cell Parameters Inverters

-Operating Inverters-Shutdown Distribution Systems-Operating Dist ri but ion Sys terns -Shutdown REFUELING OPERATIONS Boron Concentration Nuclear Instrumentation Containment Penetrations Residual Heat Removal (RHR) and Coolant Circulation-High Water Level Residual Heat Removal (RHR) and Coolant Circulation-Low Water Level Refueling Cavity Water Level (continued)

Tt.lnT {\f,.I nf"'\Tt.lT

? .11,u.1.nn rVJ.1'11 J iii Amendment 233 Facility Operating License No. DPR-64 Appendix A -Technical Specifications TABLE OF CONTENTS 4.0 4 .1 4.2 4.3 5.0 5.1 5.2 5.3 5.4 5.5 5. 5 .1 5.5.2 5. 5. 3 5.5.4 5. 5. 5 5.5.6 5. 5. 7 5.5.8 5.5.9 5. 5 .10 5. 5 .11 5.5.12 5. 5 .13 5.5.14 5.5.15 5.5.16 5.6 5. 6 .1 5.6.2 5.6.3 5.6.4 5.6.5 5.6.6 5.6.7 5.6.8 5.7 DESIGN FEATURES Site Location Reactor Core Fuel Storage ADMINISTRATIVE CONTROLS Responsibility Organization Unit Staff Qualifications Procedures Programs and Manuals Offsite Dose Calculation Manual (ODCM) Primary Coolant Sources Outside Containment NOT USED Radioactive Effluent Controls Program Component Cyclic or Transient Limit Reactor Coolant Pump Flywheel Inspection Program Inservice Testing Program Steam Generator (SG) Program Secondary Water Chemistry Program Ventilation Filter Testing Program (VFTP) Explosive Gas and Storage Tank Radioactivity Monitoring Program Diesel Fuel Oil Testing Program Technical Specification (TS) Bases Control Program Safety Function Determination Program (SFDP) Containment Leakage Rate Testing Program Control Room Envelope Habitability Program Reporting Requirements NOT USED Annual Radiological Environmental Operating Report Radioactive Effluent Release Report NOT USED CORE OPERATING LIMITS REPORT (COLR) NOT USED Post Accident Monitoring Instrumentation (PAM) Report Steam Generator Tube Inspection Report High Radiation Area INDIAN POINT 3 iv Amendment 239 u ~) 1.0 USE AND APPLICATION

1.1 Definitions

Definitions 1.1 *****************************************NOTE*******************************************

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases. Ier:m ACTIONS ACTUATION LOGIC TEST AXIAL FLUX DIFFERENCE CAFD) CHANNEL CALIBRATION INDIAN POIITT 3 Definition ACTIONS shall be that part of a Specification that prescribes*Required Actions to be taken under designated Conditions within specified Completion Times. An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices. AFD shall be the difference in normalized flux signals between the top and bottom halves of a two section excore neutron detector.

A CHANNEL CALIBRATION shall be the adjustment.

as necessary, of the channel so that it responds within the required range and accuracy to known input. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, interlock, display, and trip functions.

Calibration of instrument channels with resistance temperature detector CRTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION shall include an inplace cross calibration that compares the other sensing elements with the (continued) 1.1*1 Amenctnent 205

~I 1.1 Definitions Definitions

1.1 CHANNEL

CALIBRATION (continued)

CHANNEL CHECK CHANNEL OPERATIONAL TEST (COT) CORE ALTERATION CORE OPERATING LIMITS REPORT (COLR) INDIAN POINT 3 recently installed sensing element. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping calibrations or total channel steps so that the entire channel is calibrated.

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.

A COT shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify the OPERABILITY of required alarm, interlock, display, and trip functions.

The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.*

CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components.

within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

The COLR is the unit specific document that provides cycle specific parameter limits for the current reload cycle. These-cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification

5.6.5. Plant

operation within these limits is addressed in individual Specifications. (continued) 1.1*2 Amencknent 205

1.1 Definitions

(continued)

DOSE EQUIVALENT I-131 DOSE EQUIVALENT XE-133 LEAKAGE INDIAN POINT 3 Definitions 1.1 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes I-131, I-132, I-133, I-134, and I-135 actually present. If a specific isotope is not detected, it should be assumed to be present at the minimum detectable activity.

The determination of DOSE EQUIVALENT I-131 shall be performed using Committed Effective Dose Equivalent (CEDE) dose conversion factors from Table 2.1 of EPA Federal Guidance Report No. 11, 1988. DOSE EQUIVALENT XE-133 shall be that concentration of Xe-133 (microcuries per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-85, Kr-87, Kr-88, Xe-13lm, Xe-133m, Xe-133, Xe-135m, Xe-i35, and Xe-138 actually present. If a specific noble gas nuclid~ is not detected, it should be assumed to be present at the minimum detectable activity.

The determination of DOSE EQUIVALENT XE-133 shall be performed using effective dose conversion factors for air submersion listed in Table III.I of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionuclides in Air, Water, and Soil". The maximum allowable primary containment leakage rate, L,, shall be 0.1% of primary containment air weight per day at the calculated peak containment pressure (P,). LEAKAGE shall be: a. Identified LEAKAGE 1. LEAKAGE, such as that from pump seals or valve packing (except for leakage into closed systems and reactor coolant pump (RCP) seal water injection or leakoff), that is ca~tured and conducted to collection systems or a sump or collecting tank; (Leakage into closed systems is leakage that can be accounted for and contained by a (continued) 1.1 -3 Amendment237

1.1 Definitions

LEAKAGE (continued)

MASTER RELAY TEST MODE INDIAN POINT 3 Definitions

1.1 system

not directly connected to the atmosphere.

Leakage past the pressurizer safety valve seats and leakage past the safety injection pressure isolation valves are examples of reactor coolant system leakage into closed systems.)

2. LEAKAGE into the containment atmosphere from source~ that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or 3. Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE);

b. Unidentified LEAKAGE A 11 LEAKAGE ( except for 1 ea kage into c 1 osed sys terns and RCP seal water injection or leakoff) that is not identified LEAKAGE; c. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall, A MASTER RELAY TEST shall consist of energ1z1ng each master relay and verifying the OPERABILITY of each relay. The MASTER.RELAY TEST shall include a continuity check of each associated slave relay. A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant loop temperature, and reactor continued

1. 1 -4 Amendment 233 u 1.1 Definitions MODE (continued)

OPERABLE-OPERABILITY PHYSICS TESTS QUADRANT POWER TILT RATIO (QPTR) RATED THERMAL POWER (RTP) INDIAN POINT 3 Definitions

1.1 vessel

head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel. A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

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

These tests are: a. Described in FSAR Chapter 13, Initial Tests and Operations;

b. Authorized under the provisions of 10 CFR 50.59; or c. Otherwise approved by the Nuclear Regulatory Commission.

QPTR shall be the ratio of the maximum upper excore detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater. RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3216 MWt. (continued) 1.1 -5 Amendment 225

1.1 Definitions

(continued)

SHUTDOWN HARGIN CSDH) SLAVE RELAY TEST STAGGERED TEST BASIS THERHAL POWER INDIAN POINT 3 Definitions 1.1 SDH shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All rod cluster control assemblies CRCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. -With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDH: and b. In HODES 1 and 2, the fuel and moderator temperatures are changed to the hot zero power level. A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay. The SLAVE RELAY TEST shall include, as a minimum. a continuity check of associated testable actuation devices. 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.

THERHAL POWER shall be the total reactor core heat transfer rate to the reactor coolant. (continued) 1.1-6 Amencinent 205 V 1.1 Definitions (continued)

TRIP ACTUATING DEVICE OPERATIONAL TEST CTADOT> INDIAN POINT 3 A TADOT shall consist of operating the trip Definitions

1.1 actuating

device and verifying the OPERABILITY of required alarm. interlock.

display. and trip functions.

The TADOT shall include adjustment.

as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

1.1-7 lvnenctnent 205 HOOE TITLE 1 Power Operation 2 Startup 3 Hot Standby 4 Hot Shutdown<b) 5 Cold Shutdown<b) 6 RefuelingCc)

Ca) Excluding decay heat. Table 1.1-1 (page 1 of 1) HODES Y. RATED REACTIVITY THERMAL CONDITION POWER(a) Ckett> 0.99 > 5 0.99 :s: 5 < 0.99 NA < 0.99 NA < 0.99 NA NA NA Cb) All reactor vessel head closure bolts fully tensioned.

Definitions

1.1 AVERAGE

REACTOR COOLANT TEMPERATURE (OF) NA NA 350 350 > Tavg > 200 :s: 200 NA Cc) One or more reactor vessel head closure bolts less than fully tensioned.

INDIAN POINT 3 1.1-8 Amenctnent 205 Logical Connectors 1.2 1.0 USE AND APPLICATION

1.2 Logical

Connectors PURPOSE BACKGROUND INDIAN POINT 3 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 DB. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

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 indentations 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.

1.2-1 (continued) lvnenonent 205 u LogJcal Connectors 1.2 1.2 Logical Connectors (continued)

EXAMPLES INDIAN POINT 3 The following examples illustrate the use of logical connectors.

EXAMPLE 1,2*1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. LCO not met. A.l Verify . A.2 Restore . . . In this example the logical connector AliQ is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

• (continued) 1.2*2 Amenanent 205 Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1.2*2 ACTIONS CONDITION A. LCO not met. REQUIRED ACTION COMPLETION TIHE A.1 Trip * . . .QB A.2.1 Verify. . . MD A.2.2.1 Reduce .QB A.2.2.2 Perform . .QB 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 .QB 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 At:!Q. 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 .QB indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

1.2*3 lvnendnent 205 u u Completion Times 1.3 1.0 USE AND APPLICATION

1.3 Completion

Times PURPOSE BACKGROUND DESCRIPTION INDIAN POINT 3 The purpose of this section is to establish the Completion Time convention and to provide guidance for its use. 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). 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 HOOE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

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

Once a Condition has been entered. subsequent trains, subsystems.

components, or variables expressed in the Condition, discovered to *be inoperable or not within limits, will nnt result in separate entry into the Condition.

unless specifically stated. The Required Actions of the Condition continue to apply to each (continued) 1.3*1 twendment 205 V u Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued)

INDIAN POINT 3 additional failure, with Completion Times based on initial entry into the Condition.

However, when a subsequent train, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits. the Completion Time(s) may be extended.

To apply this Completion Time extension.

two criteria must first be met. The subsequent inoperability:

a. Hust exist concurrent with the .fi.c.s1 inoperability; and b. Hust 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 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: or b. The stated Completion Time as measured from discovery of the subsequent inoperability.

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

These exceptions are stated in individual Specifications.

The above Completion Time extension.does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase ~from discovery

.*. " Example 1.3*3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and Bin Example 1.3*3 may not be extended. (continued)

/lmencinent 205 u u Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES INDIAN POINT 3 The following examples illustrate the*use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1,3*1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated Mill Completion Time not met. B.2 Be in HOOE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition Bis entered. The Required Actions of Condition Bare to be in MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ANO in HOOE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. A total of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (not 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br />) is allowed for reaching HOOE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />. the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days <br />0.00917 hours <br />5.456349e-5 weeks <br />1.25565e-5 months <br /> because the total time allowed for reaching HOOE 5 is 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. If Condition Bis entered while in HOOE 3, the time allowed for reaching MODE 5 is the next_36 hours. (continued) 1.3*3 Amenanent 205 u u Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) . I INDIAN POINT 3 EXAMPLE 1.3-2 ACTIONS CONDITION A. One pump inoperable.

B. Required Action and associated Completion Time not met. REQUIRED ACTION COMPLETION TIHE A.1 Restore pump to 7 days OPERABLE status. B.1 Be in HODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Mm B.2 Be in HODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> When a pump is declared inoperable.

Condition A is entered. If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition Bis entered, Condition A and Bare 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 ente~ed, 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) 1.3-4 Amencinent 205 u Completion Times 1.3 1.3 Completion Times EXAMPLES INDIAN POINT 3 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 Bis 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 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for > 7 days. (continued) 1.3*5 Amenanent 205 V V 1.3 Completion Times EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1,3*3 ACTIONS CONDITION A. One Function X train inoperable.

B. One Function Y train inoperable.

C. One Function X train inoperable.

Mm One Function Y train inoperable.

REQUIRED ACTION A.1 Restore Function X train to OPERABLE status. B.1 Restore Function Y train to OPERABLE status. C.1 Restore Function X train to OPERABLE status. OB C.2 Restore Function Y train to OPERABLE.

status. 1.3*6 Completion Times 1.3 COMPLETION TIME 7 days AHO 10 days from discovery of failure to meet the LCO 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AHO 10 days from discovery of failure to meet the LCO 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours (continued)

Amendment 205 u V Completion Times 1.3 1.3 Completion Times EXAMPLES INDIAN POINT 3 EXAMPLE 1.3-3 (continued)

When one Function X train and one Function Y train are inoperable.

Condition A and Condition Bare concurrently applicable.

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

If Required Action C.2 is completed within the specified Completion Time, Conditions Band Care exited. If the Completion Time for Required Action A.1 has not expired. operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A). The Completion Times of Conditions A and Bare 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 c011111encing at the time the LCO was initially not met. instead of at the time the associated Condition was entered. * (continued) 1.3*7 Amenctnent 205 Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1. 3

• 4 ACTIONS CONDITION A. One or more valves inoperable.

B. Required Action and associated Completion . Time not met. REQUIRED ACTION COMPLETION TIHE A.1 Restore valve(s) to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> OPERABLE status. B.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> MID B.2 Be in HOOE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable.

while Condition A is still in effect, does not trigger the tracking of separate Completion Times. Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset. but continues from the time the first valve was declared inoperable.

The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> provided this does not result in any subsequent valve being inoperable for> 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. If the Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> (including the extension) expires while one or more valves are still inoperable, Condition Bis entered. (continued) 1.3*8 Amendment 205 V V Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1.3-5 ACTIONS *******************************NOTE*********************************

Separate Condition entry is allowed for each inoperable valve. CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more A.1 Restore valve to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> valves OPERABLE status. inoperable.

8. Required 8.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated MID Completion Time not met. 8.2 Be in HOOE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table. 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) 1.3*9 Amendnent 205

\..__) Completion Times 1.3 1.3 Completion Times EXAMPLES INDIAN POINT 3 EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires, Condition Bis entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition Bis entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition Bis restored to OPERABLE status. Condition Bis exited for that valve. Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply. EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per a hours inoperable.

OR A.2 Reduce THERMAL POWER to s 50% RTP. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and associated Completion Time not met. (continued) 1.3-10 Menanent 205 u Completion Times 1.3 1.3 Completion Times EXAMPLES INDIAN POINT 3 EXAMPLE 1.3-6 (continued)

Entry into Condition A offers a choice between Required Action A.I or A.2. Required Action A.I has a "once per" Completion Time, which qualifies for the 25% extension.

per SR 3.0.2. to each performance after the initial performance.

The initial 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval.

If Required Action A.I is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2). Condition Bis entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> is not met, Condition Bis entered. If after entry into Condition B. Required Action A.I or A.2 is met. Condition Bis exited and operation may then continue in Condition A. (continued) 1.3-11 lwenanent 205 u Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1.3-7 ACTIONS CONDITION A. One subsystem inoperable.

B. Required Action and associated Completion Time not met. REQUIRED ACTION COMPLETION TIHE A.l Verify affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> subsystem isolated.

Atm Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter Mill A.2 Restore subsystem to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status. 8.1 Be in HODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Mill 8.2 Be in HODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter" interval begins upon performance of Required Action A.1. (continued) 1.3-12 Amenonent 205 u u Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1,3*7 (continued)

If after Condition A is entered. Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or any subsequent 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval from the previous performance (plus the extension allowed by SR 3.0.2). Condition Bis entered. The Completion Time clock for Condition A does not stop after Condition Bis entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition Bis 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 COMPLETION TIME INDIAN POINT 3 When "Irrmediately" is used as a Completion Time, the Required Action should be pursued without delay and in a controlled manner. 1.3*13 nienanent 205 u u u Frequency 1.4 1.0 USE AND APPLICATION

1.4 Frequency

PURPOSE DESCRIPTION EXAMPLES INDIAN POINT 3 The purpose of this section is to define the proper use and application of Frequency requirements.

Each Surveillance Requirement CSR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR. The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement CSR) 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.

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 following examples illustrate the various ways that Frequencies are specified.

In these examples, the Applicability of the LCO CLCO not shown) is HODES 1, 2, and 3. (continued) 1.4*1 Pmenanent 205

1.4 Frequency

EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE Perform CHANNEL CHECK. Frequency

1.4 FREQUENCY

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval.

Although the Frequency is stated as 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility.

The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable.

The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1} and LCO 3.0.4 becomes applicable. (continued) 1.4 -2 Amendment 234 u u 1.4 Frequency EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1.4*2 SURVEILLANCE REQUIREMENTS SURVEILLANCE Verify flow is within limits. Frequency

1.4 FREQUENCY

Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 25%' RTP 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter Example 1.4*2 has two Frequencies.

The first is a one time performance Frequency, and the second is of the type shown in Example 1.4*1. The logical connector"~" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level< 25%' RTP to~ 25%' RTP, the Surveillance must be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "Alli!").

This type of Frequency does not qualify for the 25%' extension allowed ~Y 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) 1.4*3 IIJllenanent 205

\._,,) u 1.4 Frequency EXAMPLES (continued)

INDIAN POINT 3 EXAMPLE 1,4*3 SURVEILLANCE REQUIREMENTS SURVEILLANCE

• • • • • • • • • • • • • • • • • • NOTE*********************

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

Frequency

1.4 FREQUENCY

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

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

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

but operation was< 25X RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing HODES, even with*the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> with power~ 25X RTP. Once the unit reaches 25X RTP, 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> would be allowed for completing the Surveillance.

If the Surveillance were not performed within this 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply. 1.4*4 htenanent 205 u u SLs 2.0 2 .1 SLs 2.2 ..2. 1 .1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Vessel inlet temperature, and pressurizer pressure shall not exceed the limits specified in the COLR; and the following SLs shall not be exceeded:

2.1.1.1 The departure from nucleate boiling ratio (DNBR) shall be maintained>

1.17 for the WRB-1 DNB correlations.

2.1.1.2 The peak fuel centerline temperature shall be maintained<

5080°F, decreasing by 58°F per 10,000 MWD/MTU of burnup. 2.1.2 RCS Pressure SL ' In MODES 1, 2, 3, 4, 5, and in MODE 6 wnen the reactor vessel head is on, the RCS pressure shall be maintained~

2735 psig. SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. 2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. 2.2.2.2 In MODE 3, 4, 5, or 6, restore compliance within 5 minutes. INDIAN POINT 3 2.0-1 Amendment 225 LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCO 3.0.2 LCO 3.0.3 INDIAN POINT 3 LCOs shall be met during the MODES or other specified conditions in the Applicability, 1!xcept as provided in LCO 3.0.2 1 LCO 3.0.7 and LCO 3.0.8. 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 Compl1!tion Time(s). completion of the Required Action(s) is not required unless otherwise stated. When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable.

Action shall be initiated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, in: a. MODE 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />; b. MODE 4 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />; and c. MODE 5 within 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br />. Exceptions to this Specification are stated in the individual Specifications.

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

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4. (continued) 3.0 -1 Amendment 229 LCO 3.0.4 LCO 3.0.5 u INDIAN POINT 3 LCO Applicability 3.0 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made: a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or c. When an allowance is stated in the individual value, parameter, or other Specification.

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.* Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment.

This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY. (continued) 3.0 -2 Amendment 226 LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.6 LCO 3.0.7 LCO 3.0.8 INDIAN POINT 3 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 5.5.14, "Safety Function Determination Program (SFDP).11 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. Test Exception LCOs~ such as 3.1.8, allow specified Technical Specification (TS) ,*equirements to be changed to permit performance of special tests and operations.

Unless otherwise specified, all other TS requirements remain unchanged.

Compliance with Test Exception LCOs is optional.

When a Test Exception LCO is desired to be met but is not mE!t, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and: a. the snubbers not able to perform their associated support function(s) ar1! associated with only one train or subsystem of a multiple tra"in or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; or b. the snubbers nc1.t able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported s.ystem LCO(s) shall be declared not met. 3.0 -3 Amendment 229 u SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SR 3.0.2 SR 3.0.3 INDIAN POINT 3 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. -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 *** 11 basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance.

A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and the risk impact shall be managed. If the Surveillance is not performed within the delay period, the LCO must irnnediately be declared not met, and the applicable Condition(s) must be entered. When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must irnnediately be declared not met, and the applicable Condition(s) must be entered. (continued) 3.0 -4 Amendment 212 V SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.4 INDIAN POINT 3 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. 3.0 -5 Amendment 226 .,

u . 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) LCO 3.1.1 APPLICABILITY:

ACTIONS SDM shall be within the limits specified in the COLR. MODE 2 with kett < 1.0, HODES 3, 4, and 5. SDM 3.1.1 CONDITION REQUIRED ACTION COMPLETION TIHE A. SDH not within limit. A.l SURVEILLANCE REQUIREMENTS SURVEILLANCE Initiate boration to restore SDH to within limit. 15 minutes FREQUENCY SR 3.1.1.1 Verify SDH is within the limits specified in the *24 hours COLR. INDIAN POINT 3 3.1.1*1 Amenanent 205 V V 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity Core Reactivity 3.1.2 LCO 3.1.2 The measured core reactivity shall be within+/- 1% 6k/k of predicted values. APPLICABILITY:

HODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION CO HP LET ION TI HE A. Measured core reactivity A.1 Re*evaluate core design 7 days not within limit. and safety analysis.

and determine that the reactor core is acceptable for continued operation.

MID A.2 Establish appropriate 7 days operating restrictions and SRs. B. Required Action and B.1 Be in HOOE 3.-. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. INDIAN POINT 3 3.1.2*1 Amenanent 205 V SURVEILLANCE REQUIREHENTS SR 3.1.2.1 INDIAN POINT 3 SURVEILLANCE

---

NOTE -----. -----------------The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days CEFPD) after each fuel loading. Verify measured core reactivity is within +/- 1% ~k/k of predicted values. 3.1.2*2 Core Reactivity

3.1.2 FREQUENCY

Once prior to entering HOOE 1 after each refueling Only required after 60 EFPD 31 EFPD thereafter Amenonent 205 u 3.1 REACTIVITY CONTROL SYSTEHS 3.1.3 Hoderator Temperature Coefficient (HTC) HTC 3.1.3 LCO 3.1.3 The HTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be~ 0.0 Ak/k°F at hot zero power. APPLICABILITY:

HOOE 1 and HOOE 2 with kett 1.0 for the upper HTC limit, HODES 1, 2, and 3 for the lower HTC limit. ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. HTC not within upper A.1 Establish administrative 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> limit. withdrawal limits for control banks to maintain HTC within limit. B. Required Action and B.1 Be in HOOE 2 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion kett < 1.0. Time of Condition A not met. C. HTC not within 1 ower C.1 Be in HOOE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> limit. INDIAN POINT 3 3.1.3*1 Amenctnent 205 SURVEILLANCE REQUIREMENTS SR 3.1.3.1 SR 3.1.3.2 INDIAN POINT 3 SURVEILLANCE Verify MTC is within upper limit. -------------------NOTES----------------

1. Not required to be performed until 7 effective full power days (EFPD) after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm. 2. SR 3.1.3.2 is not required to be performed by measurement provided that the benchmark criteria in WCAP-137 49-P-A are satisfied and the Revised Predicted MTC satisfies the 300 ppm surveillance limit specified in the COLR. 3. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle. 4. SR 3.1.3.2 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of s 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COLR. Verify MTC is within lower limit. 3.1.3-2 FREQUENCY Once prior to entering MODE 1 after each refueling Once each cycle MTC 3.1.3 Amendment 261 u u Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with rod group alignment limits as follows: a. *when THERMAL POWER is> 85% RTP, the difference between each individual indicated rod position and its group step counter* demand position shall be within the limits specified in Table 3.1.4-1 for the group step counter demand position:

and b. When THERMAL POWER is~ 85% RTP, the difference between each individual indicated rod position and its group step counter demand position shall be within 24 steps. APPLICABILITY:

HODES 1 and 2. ACTIONS CONDITION A. One or more rod(s) untrippable.

INDIAN POINT 3 A.1.1 OB A.1.2 MD A.2 REQUIRED ACTION COMPLETION TIME Verify SDM is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits specified in the COLR. Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit. Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (continued) 3.1.4-1 lwendment 205 ACTIONS (continued)

CONDITION B. One rod not within alignment limits. u INDIAN POINT 3 B.1 QB B.2.1.1 8.2.1.2 ANO B.2.2 ANO *B.2.3 Mm B.2.4 Mm B.2.5 ANO Rod Group Alignment Limits 3.1.4 REQUIRED ACTION COMPLETION TIHE Restore rod to within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> alignment limits. Verify SOM is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits specified in the COLR. QB Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit. Reduce THERMAL POWER to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 75% RTP. Verify SDH is within the Once per limits specified in the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> COLR. Perform SR 3.2.1.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ' Perform SR 3.2.2.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> {continued) 3.1.4*2 Amenanent 205 ACTIONS u CONDITION B (continued)

B.2.6 C. Required Action and C.1 associated Completion Time of Condition B not met. D. Hore than one rod not D.1.1 within alignment limit. OR D.1.2 M:!Q D.2 u INDIAN POINT 3 Rod Group Alignment Limits 3.1.4 REQUIRED ACTION COMPLETION TIHE Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Verify SDH is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits specified in the COLR. Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore required SDH to within .limit. Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 3.1.4-3 .t.mendment 205 Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SR 3.1.4.1 SR 3.1.4.2 SR 3.1.4.3 INDIAN POINT 3 SURVEILLANCE

NOTE************************

Not required to be met for individual control rods until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after completion of control rod movement.

Verify individual rod positions within alignment limit. Verify rod freedom of movement Ctrippability) by moving each rod not fully inserted in the core 10 steps in one direction.

Verify rod drop time of each rod, from the fully withdrawn position.

is$ 1.8 seconds from the loss of stationary gripper coil voltage to dashpot entry, with: a. Tavg 500°F: and b. All reactor coolant pumps operating.

3.1.4*4 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 92 days Prior to reactor criticality after each removal of the reactor head Amenanent 205 V Table 3.1.4*1 Rod Group Alignment Limits 3.1.4 Haximum Permissible Rod Hisalignment (Indicated Rod Position minus Group Step Counter Demand Position)

When> 85 X RTP Step Counter Demand Maximum Permissible Deviations Position CIRPI Position.minus Step Counter Demand Position) (steps) (steps) 212 *12 and +12 213 to 225 *12 and +17. 226 *13 and +17 227 -14 and +17 228 *15 and +17 229 *16 and +17 230 *17 and +17 INDIAN POINT 3 3.1.4*5 . Amenanent 205 u u 3.1 REACTIVITY CONTROL SYSTEHS 3.1.5 Shutdown Bank Insertion Limits Shutdown Bank Insertion Limits 3.1.5 LCO 3.1.5 Each shutdown bank shall be within insertion limits specified in the COLR. APPLICABILITY:

HOOE 1, HOOE 2 with any control bank not fully inserted.

---

*-----------------*-----NOTE----*-*-------*******---**--

This LCO is not applicable while performing SR 3.1.4.2. ACTIONS CONDITION REQUIRED ACTION COHPLETI ON TI HE A. One or more shutdown A.1.1 Verify SDH is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> banks not within limits. limits specified in the COLR. QR A.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDH to within limit. AHO A.2 Restore shutdown banks 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to within limits. B. Required Action and B.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. INDIAN POINT 3 3.1.5*1 Amenanent 205 u Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SR 3.1.5.1 INDIAN POINT 3 SURVEILLANCE Verify each shutdown bank is within the limits specified in the COLR. 3.1.5*2 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Amenanent 205 *

3.1 REACTIVITY

CONTROL SYSTEHS 3.1.6 Control Bank Insertion Limits Control Bank Insertion Limits 3.1.6 LCO 3.1.6 Control banks shall be within the insertion, sequence.

and overlap limits specified in the COLR. APPLICABILITY:

HOOE 1, HOOE 2 with kett 1.0. *******************************NOTE*******************************

This LCO is not applicable while performing SR 3.1.4.2. ACTIONS CONDITION A. Control bank insertion limits not met. INDIAN POINT 3 A.1.1 OB A.1.2 A.2 REQUIRED ACT! ON COMPLETION TIHE Verify SOM is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits specified in the COLR. Initiate boration to restore SOM to within limit. Restore control bank(s) to within limits. 3.1.6*1 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 2 hours (continued)

Amenanent 205 u u ACTIONS (continued)

CONDITION B. Control bank sequence or B.1.1 overlap limits not met. QB B.1.2 MID * *B.2 C. Required Action and C.1 associated Completion Ti me not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE Control Bank Insertion Limits 3.1.6 REQUIRED ACTION COMPLETION TIHE Verify SDH is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits specified in the COLR. Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDH to within limit. Restore control bank 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> sequence and overlap to within ,-imits. Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is within the limits specified in the COLR. Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to achieving criticality (continued)

INDIAN POINT 3 3.1.6*2 Amencinent 205 u Control Ban~ Insertion Limits 3.1.6 SURVEILLANCE REQUIREHENTS (continued)

SR 3.1.6.2 SR 3.1.6.3 INDIAN POINT 3 SURVEILLANCE Verify each control bank insertion is within the limits specified in the COLR. Verify sequence and overlap limits specified in the COLR are met for control banks not fully withdrawn from the core. 3.1.6*3 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours Ameminent 205 u 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication Rod Position Indication 3.1.7 LCO 3.1. 7 The Individual Rod Position Indication

(!RPI) System and the Demand Position Indication System shall be OPERABLE.

APPLICABILITY:

HODES 1 and 2. ACTIONS ****************************************NOTE********************************************

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

CONDITION A. One !RPI per group inoperable for one or more groups. INDIAN POINT 3 REQUIRED ACTION

• COMPLETION TIME A.l Verify the position of Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> the rods with inoperable position indicators indirectly by using movable incore detectors.

A.2 Reduce THERMAL POWER to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> :!: 50% RTP. (continued) 3.1. 7*1 twenanent 205 ACTIONS (continued)

CONDITION

8. Hore than one IRPI per 8.1 group inoperable.

MID 8.2 MID 8.3 Mill 8.4 C. One or more rods with C.1 inoperable position indicators have been moved in excess of 24 steps in one direction since the last determination of the rod's position.

QB C.2 INDIAN POINT 3 Rod Position Indication

3.1.7 REQUIRED

ACTION COMPLETION TIHE Place the control rods Inunediately under manual control. Monitor and record RCS Once per 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Tavg._ Verify the position of Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> the rods with inoperable position indicators indirectly by u*sing the movable incore detectors.

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

Verify the position of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> the rods with inoperable position indicators indirectly by using movable incore detectors.

Reduce THERMAL POWER to SOX RTP. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> (continued) 3.1. 7-2 Amenanent 205 ACTIONS (continued)

CONDITION D. One demand position D.1.1 indicator per bank inoperable for one or more banks. MID D.1.2 .QR D.2 E. Required Action and E.1 associated CCMTipletion Time not met. INDIAN POINT 3 Rod Position Indication 3.1. 7 REQUIRED ACTION COHPLETION TIHE Verify by administrative Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> means all IRPis for. the affected banks are OPERABLE.

Verify the most Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> withdrawn rod and the least withdrawn rod of the affected banks are 12 steps apart when > 85% RTP and~ 24 steps apart when~ 85% RTP . Reduce THERHAL POWER to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> SOY. RTP. Be in HODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 3.1. 7*3 . Amendment 205 SURVEILLANCE REQUIREMENTS SR 3.1. 7 .1 V INDIAN POINT 3 SURVEILLANCE Verify each IRPI agrees within 12 steps of the group demand position for the full indicated range of rod travel.

• 3.1. 7.4 Rod Position Indication

3.1.7 FREQUENCY

Prior to reactor criticality after each removal of the reactor vessel head Amenctnent 205 V u PHYSICS TESTS Exceptions -HOOE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEHS 3.1.8 PHYSICS TESTS Exceptions-HODE 2 LCO 3.1.8 APPLICABILITY:

ACTIONS During the performance of PHYSICS TESTS, the requirements of LCO 3 .1. 3 , "Hoder a tor Temperature Coefficient C HTC) " : LCO 3.1.4, "Rod Group Alignment Limits"; LCO 3.1.5, "Shutdown Bank Insertion Limits": LCO 3.1.6, "Control Bank Insertion Limits": and LCO 3.4.2, "RCS Hinimum Temperature for Criticality" may be suspended, provided:

a. RCS lowest loop average temperature is~ 540°F; and b. SDH is within the limits specified in the COLR; and c. THERHAL POWER IS s: 5% RTP. HODE 2.during PHYSICS TESTS. CONDITION REQUIRED ACTION COHPLETION TIHE A. SDH not within limit. A.1 Initiate boration to 15 minutes restore SDH to within limit. AHO A.2 Suspend PHYSICS TESTS 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> exceptions.

B. THERHAL POWER not within B.l Open reactor trip Immediately limit. breakers. (continued)

INDIAN POINT 3 3.1.8*1 hnenanent 205 u PHYSICS TESTS Excepti ans -MODE 2 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION C. RCS lowest loop average C.1 Restore RCS lowest loop temperature not within average temperature to limit. within limit. D. Required Action and D.1 Be in MODE 3. associated Completion Time of Condition C not met. SURVEILLANCE REQUIREMENTS SR 3.1.8.1 SR 3.1.8.2 SR 3.1.8.3 SR 3.1.8.4 INDIAN POINT 3 SURVEILLANCE Perform a CHANNEL OPERATIONAL TEST on power range and intermediate range channels per SR 3.3.1.7. SR 3.3.1.8. and Table 3.3.1*1. Verify the RCS lowest loop average temperature is 540°F. Verify THERHAL POWER is*~ 5% RTP. Verify SDH is within the limits specified in the COLR. 3.1.8-2 COMPLETION TIME 15 minutes 15 minutes FREQUENCY Prior to initiation of PHYSICS TESTS 30 minutes 30 minutes 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Amenctnent 205 u u 3.2 POWER DISTRIBUTION LIHITS 3.2.1 Heat Flux Hot Channel Factor CF 0 CZ)) FoCZ) 3.2.1 LCO 3.2.1 F 0 CZ> shall be within the limits specified in the COLR. APPLICABILITY:

HODE 1. ACTIONS CONDITION A. F 0 (Z) not within limit. A.1 AtID A.2 AtID A.3 Mill A.4 INDIAN POINT 3 REQUIRED ACTION Reduce THERMAL POWER 1% RTP for each 1% F 0 (Z) exceeds limit. Reduce Power Range Neutron Flux -High trip setpoints 1% for each 1% F 0 CZ) exceeds limit. Reduce Overpower

~r trip setpoints lX for each 1% F 0 (Z) exceeds limit. Perform SR 3.2.1.1. 3.2.1-1 COHPLETION TIME 15 minutes after each F 0 (Z) determination 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each F 0 CZ) determination 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each F 0 CZ) determination Prior to increasing THERMAL POWER above the limit of Required Action A;l (continued)

Amendnent 205 u ACTIONS (continued)

CONDITION B. Required Action and associated Completion Time not met. INDIAN POINT 3 B.1 REQUIRED ACTION Be in HOOE 2. 3.2.1*2 FQCZ) 3.2.1 COMPLETION TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Amenanent 205 u SURVEILLANCE REQUIREHENTS FoCZ) 3.2.1 ****************************************NOTE********************************************

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

• SURVEILLANCE SR 3.2.1.1 Verify F 0 CZ) is within limit. INDIAN POINT 3 3.2.1-3 FREQUENCY Once after each refueling prior to THERHAL POWER exceeding 75~ RTP Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after achieving equi 1 i bri um conditions after exceeding, by ::i: 10~ RTP. the THERHAL POWER at which F 0 CZ) was 1 ast verified 31 EFPD thereafter Amendment 205

3.2 POWER

DISTRIBlTTION LIHITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor CF!H> LCO 3.2.2 F!H shall be within the limits specified in the COLR. APPLICABILITY:

HOOE 1. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. *********NOTE*********

A.1.1 Restore F!H to within 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />s* Required Actions A.2 limit. and A.3 must be completed whenever Condition A is OR entered. ....*.**..*...........

A.1.2.1 Reduce THERHAL POWER to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> u < 50%" RTP. F!H not within limit. MID A.1.2.2 Reduce Power Range 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Neutron Flux -High trip setpoints to~ 55%" RTP. MID A.2 Perform SR 3.2.2.1. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> MID (continued}

INDIAN POINT 3 3.2.2*1 /vnencinent 205 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3 ********NOTE*********

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

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP MID Prior to THERMAL POWER exceeding 75% RTP RID 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER reaching ::!: 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. INDIAN POINT 3 3.2.2*2 Amendment 205 u SURVEILLANCE REQUIREMENTS SR 3.2.2.1 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify F!H is within limits specified in the COLR. Once after each refueling prior to THERMAL POWER exceeding 75% RTP 3.2.2*3 31 EFPD thereafter lvnendment 205 u AFD (CAOC Methodology) 3.2.3 3.2 POWER DISTRIBlJTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE CAFD) {Constant Axial Offset Control CCAOC) Methodology)

LCO 3.2.3 APPLICABILITY:

ACTIONS INDIAN POINT 3 The AFD: a .. Shall be maintained within the target band about the target flux difference.

The target band is specified in the COLR. b. Hay deviate outside the target band with THERMAL POWER < 90% RTP but~ SOX RTP. provided AFD is within the acceptable operation limits and cumulative penalty deviation time is 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> during the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. The acceptable operation limits are specified in the COLR. c. Hay deviate outside the target band with THERMAL POWER < 50% RTP . ..............................

NOTES******************************

1. The AFD shall be considered outside the target band when two or more OPERABLE excore channels indicate AFD to be outside the target band. 2. With Thermal Power 50.t RTP. penalty deviation time shall be accumulated on the basis of a 1 minute penalty deviation for each 1 minute of power operation with AFD outside the target band.

• 3. With Thermal Power*< 50.t RTP and> 15% RTP. penalty deviation time shall be accumulated on the basis of a 0.5 minute penalty deviation for each 1 minute of power operation with AFD outside the*target band. 4. A total of 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> of operation may be accumulated with AFD outside the target band without penalty deviation time during surveillance of power range channels in accordance with

• SR 3.3.1.6, provided AFD is maintained within acceptable operation limits. HOOE 1 with THERMAL POWER> 15% RTP. 3.2.3*1 Amenanent 205 CONDITION A. THERHAL POWER~ 90% RTP. Rm AFD not within the target band. B. Required Action and associated Completion Time of Condition A not met. C. *********NOTE*********

Required Action C.1 must be completed whenever V Condition C is entered. *..........*..........

THERMAL POWER< 90% and 50% RTP with cumulative penalty deviation time> 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> during the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. QB THERMAL POWER< 90% and 50% RTP with AFD not within the acceptable operation limits. SURVEILLANCE*REQUIREHENTS INDIAN POINT 3 REQUIRED ACTION A.1

• Restore AFD to within target band. B.1 Reduce THERMAL POWER to < 90% RTP. C.l Reduce THERMAL POWER to < 50% RTP. 3.2.3*2 AFD (CAOC Methodology)

3.2.3 COMPLETION

TIME 15 minutes 15 minutes 30 minutes Amenanent 205 SR 3.2.3.1 SR 3.2.3.2 INDIAN POINT 3 SURVEILLANCE Verify AFD is within target band for each OPERABLE excore channel. *******************NOTE********************

Assume logged values of AFD exist during the preceding time interval.

Verify AFD is within target band and log AFD for each OPERABLE excore channel. 3.2.3*3 AFD (CAOC Methodology)

3.2.3 FREQUENCY

7 days *****NOTE******

Only required to be performed if AFD monitor alarm is inoperable Once within 15 minutes and every 15 minutes. thereafter when THERMAL POWER :t 90% RTP Once within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and every 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> thereafter when THERMAL POWER< 90% RTP (continued}

Amenctnent 205 u AFD (CAOC Hethodology)

3.2.3 SURVEILLANCE

REQUIREHENTS (continued)

SR 3.2.3.3 SR 3.2.3.4 INDIAN POINT 3 SURVEILLANCE Update target flux difference of each OPERABLE excore channel by: a. Determining the target flux difference in FREQUENCY Once within 31 EFPD after each refueling accordance with SR 3. 2. 3. 4. or Mill b. Using linear interpolation between the most 31 EFPD recently measured value, and either the thereafter predicted value for the end of cycle or 0% AFD. ----------------**--NOTE----**-***--*------

The initial target flux difference after each refueling may be determined from design predictions.

Determine, by measurement, the target flux difference of each OPERABLE excore channel. 3.2.3*4 Once within 31 EFPD after each refueling 92 EFPD thereafter Mtencinent 205

3.2 POWER

DISTRIBlJTION LIHITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR) LCD 3.2.4 . The QPTR shall be~ 1.02. APPLICABILITY:

HOOE 1 with THERHAL POWER > SOY. RTP. ACTIONS CONDITION A. QPTR not within limit. A.1 REQUIRED ACTION Reduce THERHAL POWER 3% from RTP for each lY. of QPTR > 1.00. QPTR 3.2.4 COHPLETION TIHE 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after each QPTR determination A.2 Determine QPTR after Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> A.3 INDIAN POINT 3 achieving equilibrium conditions from a THERHAL POWER reduction per Required Action A.1. Perform SR 3.2.1.1 and SR 3.2.2.1. 3.2.4-1 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium conditions from a Thermal Power reduction per Required Action A.1. Once per 7 days thereafter (continued)

Amenanent 205 ACTIONS CONDITION A. (continued) u INDIAN POINT 3 A.4 AND A.5 REQUIRED ACTION Re-evaluate safety analyses and confirm results remain valid for duration of operation under this condition.

• • • • • • • • NOTES*********

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

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

Normalize excore detectors to restore QPTR to within limits. 3.2.4*2 QPTR 3.2.4 COMPLETION TI HE Prior to increasing THERHAL POWER above the limit of Required Action A.1 Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

Amendment 205 ACTIONS CONDITION A. (continued)

A.6 B. Required Action and B.1 associated Completion Time not met. u INDIAN POINT 3 REQUIRED ACTION --------NOTE---------

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

• -*-******--*********

Perform SR 3.2.1.1 and SR 3.2.2.1. Reduce THERMAL POWER to $ 50% RTP. 3.2.4-3 QPTR 3.2.4 COMPLETION TIME Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium conditions at RTP not to exceed 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after increasing THERMAL POWER above the limit of Required Action A.1 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Amenanent 205 u SURVEILLANCE REQUIREMENTS SR 3.2.4.1 SR 3.2.4.2 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • NOTES*************************

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER 75X RTP, the remaining three power range channels can be used for calculating QPTR. 2. SR 3.2.4.2 may tie performed in lieu of this Surveillance.

Verify QPTR is within limit by calculation.

• • • • • • • • • • • • • • • • • • • NOTE*************************

Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER > 75X RTP. Verify QPTR is within limit*using the movable incore detectors.

3.2.4-4 FREQUENCY 7 days 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> QPTR 3.2.4 Amenanent 205 u u 3.3 INSTRUMENTATION

3.3.1 Reactor

Protection System (RPS) Instrumentation RPS Instrumentation 3.3.1 LCO 3.3.1 The.RPS instrumentation for each Function in Table 3.3.1*1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.1-1. ACTIONS ***************************************NOTE****************************************

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition IR111edi atel y with one or more required referenced in channels or trains Table 3.3.1*1 for the i noperab 1 e. channelCs) or train Cs). B. One Manual Reactor Trip B.1 Restore channel to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> channel inoperable.

OPERABLE status. QR B.2 Be in HOOE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> (continued)

INDIAN POINT 3 3.3.1*1 Amenctnent 205 ACTIONS (continued)

CONDITION C. One channel or train inoperable.

D. One Power Range Neutron Flux-High channel inoperable.

-INDIAN POINT 3 REQUIRED ACTION C.1 Restore channel or train to OPERABLE status . .QR C.2.1 Initiate action to fully insert all rods. Mm C.2.2 Place the Rod Control System in a condition incapable of rod withdrawal.

• • • • • • • • • • • • • • NOTES*************

1. The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing and setpoint adjustment of other channels.

2. Requirements of SR 3.2.4.2 are applicable if the Power Range Neutron Flux input to QPTR is inoperable

• ...***....**....***.............

D.1 Place channel in trip. .QR D.2 Be in HOOE 3. 3.3.1*2 RPS Instrumentation

3.3.1 COHPLETION

TI HE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> 48 hours 49 hours5.671296e-4 days <br />0.0136 hours <br />8.101852e-5 weeks <br />1.86445e-5 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)

Amenanent 205 ACTIONS (continued)

CONDITION E. One channel inoperable.

F. Required Intermediate Range Neutron Flux channel inoperable.

G. Required Source Range Neutron Flux channel inoperable.

u INDIAN POINT 3 *REQUIRED ACTION --**----*-----NOTE--------------

The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing of other channels * ..**.**......................*..

E.l Place channel in trip. QR E.2 Be in HOOE 3. F.l Suspend operations involving positive reactivity additions.

MID F.2 Reduce THERMAL POWER to < P-6. G.l Open Reactor Trip Breakers CRTBs). 3.3.1*3 RPS Instrumentation

3.3.1 COMPLETION

TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ' 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> -Imme di ate 1 y 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Immediately (continued)

Amendment 205 ACTIONS (continued)

CONDITION H. One channel inoperable.

I. One Reactor Coolant Pump Breaker Position channel inoperable.

INDIAN POINT 3 REQUIRED ACTION ******---~---*NOTE**************

The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing of other channels.

• • • • • • • • • • • • • • • • • • • • • • • • • • • • -***

H.1 Place channel in trip. Q8 H.2 Reduce THERMAL POWER to < P-7. *************NOTE***************

The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing of other channels . ..*........*...............*...*

I.1 Restore channel to OPERABLE status. OR 1.2 Reduce THERMAL POWER to < P-8. 3.3.1*4 RPS Instrumentation

3.3.1 COMPLETION

TI HE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 10 hours (continued)

Amendment 205 ACTIONS (continued)

CONDITION J. One Turbine Trip channel inoperable.

K. One train inoperable.

INDIAN POINT 3 REQUIRED ACTION **************NOTE**************

The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing of other channels . ...**..***......*.......*.*.....

J.1 Place channel in trip. QR J.2 Reduce THERMAL POWER to < P-8. *************NOTE***************

One train may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance t~sting provided the other train is OPERABLE . ..****....................***...

K.1 Restore train to OPERABLE status. OB K.2 Be in HOOE 3. 3.3.1-5 RPS Instrumentation

3.3.1 COMPLETION

TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 10 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours (continued)

Amenonent 205 ACTIONS (continued)

CONDITION L. One RTB train inoperable.

H. One or more channels inoperable.

u INDIAN POINT 3 REQUIRED ACTION **************NOTES*************

1. One train may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing, provided the other train is OPERABLE.

2. One RTB may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for maintenance on undervoltage or shunt trip mechanisms, provided the other train is OPERABLE.

.**......**.....................

L.1 Restore train to OPERABLE status. 08 L.2 Be in HOOE 3. H.1 Verify interlock is in required state for existing unit conditions.

08 H.2 Be in HOOE 3. 3.3.1*6 RPS Instrumentation

3.3.1 COMPLETION

TIHE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 7 hours 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> . 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> (continued)

Menonent 205 ACTIONS (continued)

V CONDITION N. One or more channels *N.1 inoperable.

QR N.2 0. One trip mechanism

0.1 inoperable

for one RTB. QR 0.2. V u INDIAN POINT 3 REQUIRED ACTION Verify interlock is in required state for existing unit conditions.

Be in HOOE 2. Restore inoperable trip mechanism to OPERABLE status. Be in HOOE 3. 3.3.1-7 RPS Instrumentation

3.3.1 COMPLETION

TI HE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 7 hours 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> 54 hours Amenanent 205 u SURVEILLANCE REQUIREMENTS RPS Instrumentation 3.3.1 *********~*****************************NOTE*****************************************

Refer to Table 3.3.1*1 to determine which SRs apply for each RPS Function.

• SR 3.3.1.1 SR 3.3.1.2 SR 3.3.1.3 INDIAN POINT 3 SURVEILLANCE Perform CHANNEL CHECK. *******************NOTES***********************

1. Adjust NIS channel if absolute difference is > 2%'. 2. Not required to be performed until .24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is::!: 15%' RTP. Compare results of calorimetric heat balance calculation to Nuclear Instrumentation System CNIS} channel output. *******************NOTES***********************

1. Adjust NIS channel if absolute _difference is ::!: 3%'. 2. Only required to be performed when THERMAL POWER is> 90X RTP. Compare results of the incore detector measurements to NIS AFD. 3.3.1*8 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 24 hours 31 effective full power days CEFPD} (continued}

MJenctnent 205 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.6 SR 3.3.1.7 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • • NOTE**********************

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service. Perform TADOT. Perform ACTUATION LOGIC TEST. *********************NOTE**********************

Only required to be performed when THERHAL POWER is > 90% RTP. Calibrate excore channels to agree with incore detector measurements.

• * * * * * * * * * * * *******-NOTE************************

Not required to be performed for source range instrumentation prior to entering HOOE 3 from HOOE 2 until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after entry into HOOE 3. Perform COT. 3.3.1*9 RPS Instrumentation

3.3.1 FREQUENCY

31 days on a STAGGERED TEST BASIS 31 days on a STAGGERED TEST BASIS 92 EFPD 92 days (continued)

/>Jnenanent 205 u u SURVEILLANCE REQUIREHENTS (continued)

SR 3.3.1.8 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • • NOTE**********************

This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

Perform COT. 3.3.1-10 RPS Instrumentation

3.3.1 FREQUENCY

• • • • • • NOTE******

Only required when not performed within prev1ous 92 days Prior to reactor startup Four hours after reducing power below P-6 for source range instrumentation Twelve hours after reducing power below P-10 for power and intermediate instrumentation Every 92 days thereafter (continued)

Amenanent 205 SURVEILLANCE REQUIREHENTS (continued)

SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.11 INDIAN POINT 3 SURVEILLANCE

---

*--NOTE*---------*-----------

Verification of setpoint is not required.

Perform TADOT. ------------* -* ------NOTE ----* --------------* -* This Surveillance shall include verification that the time constants are adjusted to the prescribed values. Perform CHANNEL CALIBRATION.

---

NOTE-------------* ---------Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

3.3.1-11 RPS Instrumentation

3.3.1 FREQUENCY

92 days 24 months 18 months for Function 11 24 months (continued)

Amenanent 205 u u u SURVEILLANCE REQUIREHENTS (continued)

SR 3.3.1.12 SR 3~3.1.13 SR 3.3.1.14 INDIAN POINT 3 SURVEILLANCE

---

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

This Surveillance shall include verification that the electronic dynamic compensation time constants are set at the required values. Perform CHANNEL CALIBRATION.

Perform COT. ---------------------NOTE----------------------

Verification of setpoint is not required.

Perform TADOT. . .J 3.3.1-12 RPS Instrumentation

3.3.1 FREQUENCY

24 months 24 months 24 months Amendment 205

1. 2. 3. (a) (b) (c) 0) RPS Instrumentation

3.3.1 Table

3.3.1-1 (page 1 of 8) Reactor Protection System Instrumentation APPLICABLE FUNCTION MODES OR OTHER SPECIFIED CONDITIONS REQUIRED SURVEILLANCE CHANNELS CONDITIONS REQUIREMENTS Manual Reactor 1,2 2 B SR 3.3.1.14 Trip 3(a), 4(a), 5(a) 2 C SR 3.3.1.14 Power Range Neutron Flux a. High 1,2 40) D SR 3.3.1.1 SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.11 b. Low 1!b>,2 40) E SR 3.3.1.1 ., *. ; ... ~*~.t~,~ SR 3.3.1.8 SR 3.3.1.11 Intermediate 1!b>, 2<c) 1 F SR 3.3.1.1 Range Neutron SR 3.3.1.8 Flux SR 3.3.1.11 With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

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

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

Only 3 channels required during Mode 2 Physics Tests, LCO 3.1.8 ALLOWABLE VALUE NA NA S111% RTP ~5%RTP NA (continued)

INDIAN POINT 3 3.3.1-13 Amendment 225 Revised by letter dated D:canber a:>, ms V FUNCTION 4. Source Range Neutron Flux 5. Overtemperature AT 6. Overpower AT Table 3.3.1*1 (page 2 of 8) Reactor Protection System Instrunentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SlRVEILLANCE CONDITIONS

• CHANNELS CONDITIONS REQUIREMENTS 2Cd) 1 G SR 3.3.1.1 SR 3.3.1.8 SR 3.3.1.11 1 1.2 4 1.2 4 G E E SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.11 SR 3.3.1.1 SR 3.3.1.3 SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.12 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.12 RPS Instrumentation

3.3.1 ALLOWABLE

VALUE NA NA Refer to Note 1 Refer to Note 2 (continued) (a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted. (d) Below the P*6 (Intermediate Range Neutron Flux) interlocks.

INDIAN POINT 3 3.3.1-14 Amenanent 205 u u u FUNCTION 7. Pressurizer Pressure a. Low b. High 8. Pressurizer Water Level -High 9. Reactor Coolant Flow-Low Table 3.3.1-1 (page 3 of 8) Reactor Protection System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS 1<e) 4 H 1,2 3 E 1<e) 3 H 1<e) 3 per loop H (e) Above the P-7 (Low Power Reactor Trips Block) interlock.

INDIAN POINT 3 3.3.1-15 RPS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS ALLOWABLE VALUE SR 3.3.1.1 ~1900 psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.1 SR 3.3.1.7 S2400 psig SR 3.3.1.10 SR 3.3.1.1 S97% SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.1 ~90% SR 3.3.1.7 SR 3.3.1.10 (continued)

Amendment 225 u u u FUNCTION 10. Reactor Coolant P~ (RCP) Breaker Position a. Single Loop b. Two Loops 11. Undervoltage RCPs (6.9 kV bus) 12. Under frequency RCPs (6.9 kV bus) 13. Steam Generator (SG) Water Level -Low Low 14. SG Water Level -Low Coincident with Steam Flow/ Feect,,;,ater Flow Mismatch Table 3.3.1*1 (page 4 of 8) Reactor Protection System Instrl.JT'lentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED Sl.RVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS 1 (f) 1 per RCP 1Cg) 1 per RCP 1<e) 1 per bus 1 Ce) l per bus 1.2 3 per SG 1.2 2 per SG 1.2 2 per SG I H H H E E E SR 3.3.1.14 SR 3.3.1.14 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.l.1 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.10 (e) Above the p.7 (Low Power Reactor Trips Block) interlock.

Cf) Above the P*B (Power Range Neutron Flux) interlock.

RPS Instrumentation

3.3.1 ALLOWABLE

VALUE NA NA NA 2 57.22 Hz 2 4.0l' HR NA NA C continued) (g) Above the p.7 (Low Power Reactor Trips Block) interlock and below the P*B (Power Range Neutron Flux) interlock.

INDIAN POINT 3 3.3.1-16 Amenanent 205 RPS Instrumentation 3.3.1 u Table 3.3.1*1 (page 5 of 8) Reactor Protection System Instrllllentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SI.RVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE 15. Turbine Trip*Auto*

1 Ch) 3 J SR 3.3.1.10 NA Stop Oil Pressure SR 3.3.1.14 16. Safety Injection 1.2 2 trains K SR 3.3.1.14 NA (SI) Input from Engineered Safety Feature Actuation System (ESFAS) 17. Reactor Trip System Interlocks

a. Intermediate 2 Cd) 2 trains H SR 3.3.1.11 NA Range Neutron SR 3.3.1.13 Flux. P*6 b. Low Power 1 2 trains N SR 3.3.1.11 NA Reactor Trips SR 3.3.1.13 Block, p.7 c. Power Range 1 4 N SR 3.3.1.11 NA Neutron Flux. SR 3.3.1.13 P*8 d. Power Range 1.2 4 H SR 3.3.1.11 NA Neutron Flux, SR 3.3.1.13 P*lO e. Turbine First 1 2 N SR 3.3.1.1 NA Stage Pressure.

SR 3.3.1.10 p.7 Input

• SR 3.3.1.13 (contfoued) j Cd) Below the P*6 (Intermediate Range Neutron Flux) interlocks. (h) Above the P*8 (Power Range Neutron Flux) interlock..

u INDIAN POINT 3 3.3.1-17 Amencinent 205 u u FUNCTION 18. Reactor Trip . Breakers(RTBs)Ci)

19. Reactor Trip Breaker Undervoltage and Shunt Trip Mechanisms

20. Automatic Trip Logic Table 3.3.1*1 (page 6 of 8) Reactor Protection System InstrLJnentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS 1.2 2 trains L SR 3.3.1.4 3(a). 4 ca>. 5 ca) 2 trains C SR 3.3.1.4 1.2 1 each 0 SR 3.3.1.4 per RTB 3 ca>. 4 Ca>. 5 Ca) 1 each C SR 3.3.1.4 per RTB 1.2 2 trains K SR 3.3.1.5 3Ca>, 4 ca>. 5 (a) 2 trains C SR 3.3.1.5 RPS Instrumentation

3.3.1 ALLOWABLE

VALUE NA NA NA NA NA NA (a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

Ci) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB. INDIAN POINT 3 3.3.1*18 Amenanent 205 Table 3.3.1-1 (page 7 of 8) Reactor Protection System Instrumentation Note 1: Overtemperature 6T RPS Instrumentation

3. 3 .1 The Overtemperature

~T Function Allowable Value shall not exceed the following Trip Setpoint by more than 2.8% of T span: Where: ~Tis measured RCS ~T. °F. ~T 0 is the indicated

~Tat RTP, °F. s is the Laplace transform operator, sec-1* Tis the measured RCS average temperature, °F. T' is the nominal Tavg at RTP,::;; [ * ]°F. Pis the measured pressurizer pressure, psig P' is the nominal RCS operating pressure, [ *] psig K1 ::;; [ * ] K 2 [ * ] /°F K 3 [ * ] /psi g r, [ * ] sec r2 ::;; [ * ] sec f 1 (~1) = [ *] {[ *] -(qt -qb)} when qt -qb::;; [ * ]% RTP 0% of RTP when [ * ]% RTP < qt -qb::;; [ * ]% RTP [ * ] { (qt -qb) -[ * ] } when qt -qb > [ * ]% RTP Where qt and qb are percent RTP in the upper and lower halves of the core, respectively, and qt+ qb is the total THERMAL POWER in percent RTP. The values denoted with [ *] are specified in the COLR. I INDIAN POINT 3 3.3.1-19 Amendment 234 RPS Instrumentation

3. 3 .1 Table 3.3.1-1 {page 8 of 8) Reactor Protection System Instrumentation Note 2: Overpower

~T The Overpower tJ. T Function A 11 owab 1 e Va 1 ue sha 11 not exceed the fo 11 owing Trip Set point by more than 1.8% of tJ. T span: Where: b.T is measured RCS /:J.T, °F. /:J.T 0 is the indicated

!J.T at RTP, °F. s is the Laplace transform operator, sec-1* Tis the measured RCS average temperature, °F. T" is the nominal T.~ at RTP, s [ * ]°F. r 3 [ * ] sec K 5 [ * ] /°F for increasing Tavg [ *] /°F for decreasing T.~ *The values denoted with [ *] are specified in the COLR .. INDIAN POINT 3 3.3.1-20 K 6 [ * ] /°F when T > T' [ * ] /°F when T :5: T' Amendment 234

3.3 INSTRUMENTATION

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

APPLICABILITY:

According to Table 3.3.2-1. ACTIONS -------------------------------------------NOTE--------------------------

Separate Condition entry is allowed for each Function.

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

inoperable.

B. One channel or B.1 Restore channel or 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> train inoperable.

train to OPERABLE status. OR -B.2.1 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> AND -------NOTE --------LCO 3.0.4.a is not applicable when entering MODE 4. -------------------

B.2.2 Be in MODE 4. 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br /> (continued)

INDIAN POINT 3 3.3.2-1 Amendment 252 ACTIONS (continued)

CONDITION C. One train inoperable.

D. One channel inoperable.

INDIAN POINT 3 C.l OR C.2.1 AND --C.2.2 D.1 OR D.2.1 AND --D.2.2 ESFAS Instrumentation

3.3.2 REQUIRED

ACTION COMPLETION TIME ------NOTE----------

One train may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing provided the other train is OPERABLE.

---

Restore train to OPERABLE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> status. Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> -----NOTE LCO 3.0.4.a is not applicable when entering MODE 4. ------------

---

Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> ---------NOTE-

---The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing of other channels.

---

---

Place channel in trip. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> (continued) 3.3.2 -2 Amendment 252 ACTIONS (continued)

CONDITION E. One Containment Pressure E.1 channel i~operable in one or both sets of three. QR E.2.1 Mm E.2.2 u F. One channel or train F.1 inoperable.

QR F.2.1 Mm F.2.2 u INDIAN POINT 3 REQUIRED ACTION *********NOTE**********

One additional channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing . .......................

Place channel in trip. Be in HOOE 3. Be in HOOE 4. Restore channel or train to OPERABLE status. -Be in HOOE 3. Be in HOOE 4. *. 3.3.2*3 ESFAS Instrumentation

3.3.2 COHPLETION

TI HE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> 48 hours 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> 60 hours (continued)

Amencinent 205 ACTIONS (continued)

CONDITION G. One train inoperable.

G.1 08 G.2.1 Mm G.2.2 H. One train inoperable.

H.1 08 H.2 u INDIAN POINT 3 REQUIRED ACTION * ********NOTE**********

One train may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing provided the other train is OPERABLE.

• • • • -****************--

Restore train to OPERABLE status. Be in HOOE 3. Be in HOOE 4. *********NOTE**********

One train may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing provided the other train is OPERABLE.

• • • • • • • • • • • • • • • • • -*****

Restore train to OPERABLE status. Be in HOOE 3. 3.3.2*4 ESFAS Instrumentation

3.3.2 COMPLETION

TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued) .Amendment 205 ACTIONS (continued)

CONDITION I. Hain Feedwater Pump trip I.1 .channel(s) inoperable.

MID I.2 J. Required Action and J.1 associated Completion Time of Condition I not met. \_) K. One or more channels K.1 inoperable.

OR K.2.1 AtiQ K.2.2 u INDIAN POINT 3 REQUIRED ACTION Verify one channel associated with an operating HBFP is OPERABLE.

Restore one channel associated with each operating HBFP to OPERABLE status. Be in HOOE 3. Verify interlock is in required state for existing unit condition.

Be in HOOE 3. Be in HOOE 4. 3.3.2*5 ESFAS Instrumentation

3.3.2 COMPLETION

TIME Invnedi ately 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> 6 hours 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 7 hours 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> lvnenanent 205 SURVEILLANCE REQUIREHENTS ESFAS Instrumentation 3.3.2 *--------------------------------*---*-NOTE------------------*--*-*----------------

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

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.2.2 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.2.3 Perform HASTER RELAY TEST.

• 31 days on a STAGGERED TEST BASIS SR 3.3.2.4 Perform COT. 92 days SR 3.3.2.5 Perform SLAVE RELAY TEST. 24 months SR 3.3.2.6 --------------*-----NOTE----------------------

Verification of setpoint not required for manual initiation functions . ***...**...****.**...***.....*...........*...

Perform TADOT. 24 months {continued)

INDIAN POINT 3 3.3.2-6 Amendment 205 u SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.2.7 INDIAN POINT 3 SURVEILLANCE

---

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

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

3.3.2-7 ESFAS Instrumentation

3.3.2 FREQUENCY

24 months Amenanent 205 u u \.._) 1. (a} (b} (c} (d} Table 3.3.2-1 (page 1 of 6) ESFAS Instrumentation

3.3.2 Engineered

Safety Feature Actuation System Instrumentation APPLICABLE MODES OR FUNCTION OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE Safety Injection

a. Manual Initiation 1,2,3,4 2 8 SR 3.3.2.6 NA b. Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays C. Containment 1,2,3 3 D SR 3.3.2.1 s4.80 psig Pressure-Hi SR 3.3.2.4 SR 3.3.2.7 d. Pressurizer 1,2,3(b) 3 D SR 3.3.2.1 ~1710 psig Pressure-Low SR 3.3.2.4 SR 3.3.2.7 e. High Differential 1,2,3 3 per D SR 3.3.2.1 NA Pressure steam line SR 3.3.2.4 Between Steam SR 3.3.2.7 Lines f. High Steam 1,2(d),3!d) 2 per D SR 3.3.2.1 (c} Flow in Two steam line SR 3.3.2.4 Steam Lines SR 3.3.2.7 Coincident with 1,2<d>,3(d) 1 per loop D SR 3.3.2.1 ~540.5°F Tavg-Low SR 3.3.2.4 SR 3.3.2.7 {continued)

Not used Above the Pressurizer Pressure interlock.

Less than or equal to turbine first stage pressure corresponding to 54% full steam flow below 20% load, and increasing linearly from 54% full steam flow at 20% load to 120% full steam flow at 100% load, and corresponding to 120% full steam flow above 100% load. Time delay for SI :56 seconds. Except when all MSIVs are closed. INDIAN POINT 3 3.3.2-8 Amendment 225 u ESFAS I nstr).Jmentati on 3.3.2 Table 3,3.2*1 (page 2 of 6) Engineered Safety Feature Actuation System Instrunentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SI.RVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE 1. Safety Injection (continued)

g. High Steam Flow in 1.2<d> , 3 Cd) 2 per D SR 3.3.2.1 (C) Two Steam Lines steam SR 3.3.2.4 line SR 3.3.2.7 Coincident with 1,2Cd),3Cd) 1 per 0 SR 3.3.2.1 2 500 Steam Line steam SR 3.3.2.4 psig Pressure-Low line SR 3.3.2.7 2. Containment Spray a *. Manual Initiation 1.2.3,4 2 per B SR 3.3.2.6 NA train, 2 trains b. Automatic 1.2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays c. Containment 1.2.3 2 sets E SR 3.3.2.1 " 24 psig Pressure (Hi *Hi) of 3 SR 3.3.2.4 SR 3.3.2.7 (continued) (c) Less than or equal to turbine first stage pressure corresponding to 54% full steam flow below 20% load, and increasing linearly from 54% full steam flow at 20% load to 120% full steam flow at 100% load, and corresponding to 120% full steam flow above 100% load. Time delay for SI~ 6 seconds. (d) Except when all HSIVs are closed. INDIAN POINT 3 3.3.2-9 Amendment 213 FUNCTION 3. Containment Isolation

a. Phase A Isolation (1) Manual Initiation (2) Automatic Actuation Logic and Actuation Relays (3) Safety Injection

b. Phase B Isolation (1) Manual Initiation (2) Automatic Actuation Logic and Actuation Relays (3) Contairvnent Pressure (Hi* Hi) I \,__) INDIAN POINT 3 Table 3.3.2*1 (page 3 of 6) ESFAS Instrumentation

3.3.2 Engineered

Safety Feature Actuation System Instrunentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SlRVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREHENTS 1.2.3.4 2 1.2.3,4 2 trains B C SR 3.3.2.6 SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.5 ALLOWABLE VALUE NA NA Refer to Function l (Safety Injection) for all initiation functions and requirements.

1.2.3.4 1.2.3.4 i".2.3 2 2 trains 2 sets of three 3.3.2-10 B C E SR 3.3.2.6 SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.5 SR 3.3.2.1 SR 3.3.2.4

• SR 3.3.2.7 NA NA s 24 psig (continued)

Amenonent 205 u V "-.__) FUNCTION Table 3.3.2-1 (page 4 of 6) ESFAS Instrumentation

3.3.2 Engineered

Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE 4. Steam Line Isolation

a. Manual Initiation 1,idl,3(d}

2 per F SR 3.3.2.6 NA steam line b. Automatic 1,2<d>,3(d) 2 trains G SR 3.3.2.2 NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays c. Containment 1.2{dl, 2 sets of 3 E SR 3.3.2.1 S24 Pressure (Hi-Hi) 3(d) SR 3.3.2.4 psig SR 3.32.7 d. High Steam Flow 1,2<d>, 2 per D SR 3.3.2.1 (c) in Two Steam 3{d) steam SR 3.3.2.4 Lines line SR 3.3.2.7 Coincident with 1,2(dl, 1 per loop D SR 3.3.2.1 ~540.5°F Tavg*Low 3(d) SR 3.3.2.4 SR 3.3.2.7 e. High Steam Flow 1,2<d>, 2 per steam D SR 3.3.2.1 (c) in Two Steam 3(d) line SR 3.3.2.4 Lines SR 3.3.2.7 Coincident with 1,2<d>, 1 per steam D SR 3.3.2.1 ~500 psig Steam Line 3(d) line SR 3.3.2.4 Pressure-Low SR 3.3.2.7 (c) Less than or equal to turbine first stage pressure corresponding to 54% full steam flow below 20% load, and increasing linearly from 54% full steam flow at 20% load to 120% full steam flow at 100% load, and corresponding to 120% full steam flow above 100% load. Time delay for SI :::;6 seconds. (d) Except when all MSIVs are closed. INDIAN POINT 3 3.3.2-11 Amendment 225 u FUNCTION 5. Feea.,ater Isolation

a. Safety Injection

b. SG Water Level* High High 6. Auxiliary Feect.later

a. Automatic Actuation Logic and Actuation Relays b. SG Water Level* Low Low c. Safety Injection (g) d. Loss of Offsite Power (Non SI Blackout Sequence Signal) e. Trip of Hain Boiler Feect.later PI.Jll)S Table 3.3.2*1 (page 5 of 6) ESFAS Instrumentation

3.3.2 Engineered

Safety Feature Actuation System Instrllllentation APPLICABLE HODES OR OTHER SPECIFIED CONDITIONS 1.2Ce) 1.2Ce) 1.2.3 1.2.3 REQUIRED CHANNELS 2 trains 3 per SG 2 trains 3 per SG CONDITIONS H D G D SI.RVEILLANCE REQUIREMENTS SR 3.3.2.2 SR 3.3.2.5 SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.2 SR 3.3.2.5 SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 ALLOWABLE VALUE NA s au NR NA 4.0.t NR Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

1.2.3 l (f) Cf)

• 2 2 1 per MBFP F I SR 3.3.2.6 SR 3.3.2.7 SR 3.3.2.6 200 V NA (continued) (e) Except when all HBFPDVs, or HBFRVs and associated bYPass valves are closed or isolated by a closed manual valve. Cf) Only required for HBFPs that are in operation. (g) Not required if AFW Pl.Ill> not required to be OPERABLE.

INDIAN POINT 3 3~3.2-12 Amencinent 205 FUNCTION 7. ESFAS Interlocks*

Pressurizer Pressure u INDIAN POIITT 3 Table 3.3.2*1 (page 6 of 6) ESFAS Instrumentation

3.3.2 Engineered

Safety Feature Actuation System lnstrunentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SlRVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE 1.2.3 3 K SR 3.3.2.1 NA SR 3.3.2.4 SR 3.3.2.7 3.3.2*13 /IJnenanent 205

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

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS ------------------

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

Separate Condition entry is allowed for each Function.

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

B. Required Action and 8.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.7 met. (continued)

INDIAN POINT 3 3.3.3-1 Amendment 226 .,

u ACTIONS (continued)

CONDITION C. One or more Functions with two required channels inoperable.

OR One required T hot channel and two required Core Exit Temperature channels inoperable.

QB One required T cold channel and two required SG Pressure channels inoperable.

OR One required Main Steam Line Radiation channel u and two required SG Water Level (Narrow Range) channels inoperable.

D. Required Action and associated Completion Time of Condition C not met. E. As required by Required Action D.1 and referenced in Table 3.3.3*1. F. As required by Required Action D.l and referenced in Table 3.3.3*1. INDIAN POINT 3 REQUIRED ACTION C.1 Restore one channel to OPERABLE status. 0.1 -Enter the Condition referenced in Table. 3.3.3*1 for the channel. E.1 Be in MODE 3. rum E.2 Be in MODE 4. F.l Initiate action in accordance with Specification 5.6.7. 3.3.3-2 PAM Instrumentation

3.3.3 COMPLETION

TIME 7 days Immediately 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours Inunediately Amendment

-2B5. 211 u u SURVEILLANCE REQUIREHENTS PAH Instrumentation 3.3.3 *************************************NOTE*********************************************

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAH instrumentation Function in Table 3.3.3*1. SR 3.3.3.1 SR 3.3.3.2 INDIAN POINT 3 SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

• • • • • • • • • • • • • • • • • • • NOTE********************

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

3.3.3*3 FREQUENCY 31 days As specified in Table 3.3.3-1 Amen<inent 205 PAM Instrumentation

3.3.3 Table

3.3.3-1 (page 1 of 2) Post Accident Monitoring Instrumentation FUNCTION 1. Neutron Flux 2. RCS Hot Leg Temperature (Wide Range) (T hotl 3. RCS Cold Leg Temperature (Wide Range) (T cold) 4. RCS Pressure (Wide Range) 5. Reactor Vessel Water Level 6. Containment Water Level (Wide Range) 7. Containment Water Level (Recirculation Sump) 8. Containment Pressure 9. Automatic Containment Isolation Valve Position 10. Containment Area Radiation (High Range) 11. NOT USED 12. 13. 14. Pressurizer Level SG Water Level (Narrow Range) SG Water Level (Wide Range) and Auxiliary Feedwater Flow 15. NOT USED 16. Steam Generator Pressure 17. Condensate Storage Tank Level 18. Core Exit Thermocouples-Quadrant

19. Core Exit Thermocouples-Quadrant 2 20. Core Exit Thennocouples-Quadrant 3 21. Core Exit Thennocoupl es-Quadrant 4 22. Main Steam Line Radiation

23. Gross Failed Fuel Detector 24. RCS Subcooling Margin See NOTES, next page. INDIAN POINT 3 2 REQUIRED CHANNELS 2 per loop per loop 2 2 2 2 2 per penet rat 1 on path{,) 101 2 2 2 per SG each per SG 2 per SG 2 2 (c) 2 (c) 2 (c) 2 {c) fl ow per steam line 2 2 CONDITION REFERENCED FROM REQUIRED ACTION D. l F E E E E E E E F F E F E E E E F F E SR 3.3.3.2 FREQUENCY 24 months 24 months 24 months 24 months 24 months 24 months 24 months 18 months 24 months 24 months 24 months 24 months 24 months, SGL 18 months, AFF 24 months 24 months 24 months 24 months 24 months 24 months 24 months 24 months 24 months 3.3.3-4 Amendment 228 Revised by letter dated August 5, 2009

\ u TABLE 3.3.3-1 (page 2 of 2) Post Accident Monitoring Instrumentation NOTES: PAM Instrumentation 3.3.3 (a) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated

• automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured. (b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel. (c) A channel consists of two core exit thermocouples (CETs). INDIAN POINT 3 3.3.3-5 Amendment 228

3.3 INSTRUMENTATION

3.3.4 Remote

Shutdown Remote Shutdown 3.3.4 LCO 3.3.4 The Remote Shutdown Functions shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS --------------------

NOTE ------------Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30_days Functions inoperable.

to OPERABLE status. B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND 8.2 Be in MODE4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> INDIAN POINT 3 3.3.4-1 Amendment 226 .,

Remote Shutdown 3.3.4 SURVEILLANCE REQUIREMENTS SR 3.3.4.1 SR 3.3.4.2 SR 3.3.4.3 INDIAN POINT 3 SURVEILLANCE FREQUENCY Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

Verify each required control circuit and transfer 24 months switch is capable of performing the intended function.

---

*-----------NOTE--------------*-----

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required instrumentation channel. 3.3.4-2 24 months Arnendnent 205 u LOP DG Start Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Loss of Power CLOP) Diesel Generator CDG) Start Instrumentation LCO 3.3.5 One channel per bus of the Undervoltage (480 V bus) Function and two channels per bus of the Degraded Voltage (480 V bus) Function shall be OPERABLE.

APPLICABILITY:

ACTIONS HODES 1, 2, 3, and 4, When associated DG is required to be OPERABLE by LCO 3. 8. 2. "AC Sources -Shutdown." ****************************************NOTE*********************************************

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIHE A. One required channel of A.1 Restore channel to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Undervoltage Function OPERABLE status. inoperable in one or more buses. B. One channel of Degraded 8.1 Place channel in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Voltage Function inoperable in one or more buses. (continued)

INDIAN POINT 3 3.3.5-1 Amendment 205 LOP DG Start Instrumentation

3.3.5 ACTIONS

(continued)

CONDmON REQUIRED ACTION C. Required Action and associated Completion Time not met. Two channels of Degraded Voltage Function inoperable in one or more buses. C.1 Enter applicable Condition(s) and Required Action(s) for the associated DG made inoperable by LOP 00 start instrumentation.

SURVEILLANCE REQUIREMENTS SR 3.3.5.1 SR 3.3.5.2 INDIAN POINT 3 SURVEILLANCE

~~------------~-----------N01'E-----~-------~---~~-~~--

Verification of setpoint not required Perform T ADOT. Perform CHANNEL CALIBRATION with Allowable Value as follows: a. Undervoltage (480 V bus) Relay Allowable Value~ 200 V. b. Degraded Voltage (480 V bus) Relay (Non-SI) Allowable Value~ 414 V with a time delay 5 45 seconds. c. Degraded Voltage (480 V bus) Relay (Coincident SI) Allowable Value~ 414 V with a time delay S 10 seconds. 3.3.5-2 COMPLETION TIME Immediately FREQUENCY 31 days 24months 18 months 18 months Amendment 2 31 u u Containment Purge System and Pressure Relief Line Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION

3.3.6 Containment

Purge System and Pressure Relief Line Isolation Instrumentation LCO 3.3.6 The Containment purge System and Pressure Relief Line Isolation instrumentation for each Function in Table 3.3.6*1 shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, 3, and 4, During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.

ACTIONS ***************************************NOTE*********************************************

Separate Condition entry is allowed for each Function.

CONDITION A. One radiation monitoring A.l channel inoperable.

INDIAN POINT 3 REQUIRED ACTION Restore the affected channel to OPERABLE status. 3.3.6*1 COMPLETION TIHE 7 days (continued)

Amenanent 205 u u u Containment Purge System and Pressure Relief Line Isolation Instrumentation

3.3.6 ACTIONS

(continued)

CONDITION B. *********NOTE*********

B.1 Only applicable in HOOE 1, 2, 3, or 4. One or more pressure relief line isolation Functions with one or more automatic actuation trains inoperable . . Two radiation monitoring channels inoperable.

Required Action and associated Completion Time of Condition A not met. INDIAN POINT 3 REQUIRED ACTION COMPLETION TIHE Enter applicable Irrmediately Conditions and Required Actions of LCO 3.6.3, "Containment Isolation Valves," for containment pressure relief line isolation valves made inoperable by isolation instrumentation.

3.3.6*2 (continued)

Mencinent 205 u u u Containment Purge System and Pressure Relief Line Isolation Instrumentation

3.3.6 ACTIONS

(continued)

CONDITION C. *********NOTE*********

Only applicable during CORE ALTERATIONS or movement of irradiated fuel assemblies within containment.

C.1 One or more containment C.2 purge system isolation Functions with one or more automatic actuation trains inoperable.

Two radiation monitoring channels inoperable.

Required Action and associated Completion Time for Condition A not met. INDIAN POINT 3 REQUIRED ACTION COMPLETION TIME .Place and maintain Invnediately containment purge system supply and exhaust valves in closed position.

Enter applicable Immediately Conditions and Required Actions of LCO 3.9.3, "Containment Penetrations," for containment purge system supply and exhaust isolation valves made inoperable by isolation instrumentation.

3.3.6*3 lwenanent 205 u u u Containment Purge System and Pressure Relief Line Isolation Inst~umentation

3.3.6 SURVEILLANCE

REQUIREHENTS

---

*~-------------NOTE--------------------------------------------

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge System and Pressure Relief Line Isolation Function.

SURVEILLANCE SR 3.3.6.1 Perform CHANNEL CHECK. SR 3.3.6.2 Perform ACTUATION LOGIC TEST. SR 3.3.6.3 Perform COT. SR 3.3.6.4 --------------------NOTE-----------------

Verification of setpoint is not required.

Perform TADOT. SR 3.3.6.5 Perform CHANNEL CALIBRATION.

INDIAN POINT 3 3.3.6-4 FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 31 days on a STAGGERED TEST BASIS 92 days 24 months 24 months lwenanent 205 u . I \_.. 1. 2. 3. 4. Containment Purge System and Pressure Relief Line Isolation Instrumentation

3.3.6 Table

3.3.6*1 (page 1 of 1) Containment Purge System and Pressure Relief line Isolation Instrl.lllentation FUNCTION REQUIRED SURVEILLANCE TRIP SETPOINT CHANNELS REQUIREHENTS Automatic Actuation logic and 2 trains SR 3.3.6.2 NA Actuation Relays SR 3.3.6.4 Gaseous Radiation Monitor (R*l2) 1 SR 3.3.6.1 (b) SR 3.3.6.3 SR 3.3.6.5 Particulate Radiation Monitor 1 SR 3.3.6.1 (b) CR*ll) SR 3.3.6.3 SR 3.3.6.5 ESFAS Function 1. Safety Injection.

Refer to LCO 3.3.2. ESFAS Instrl.lllentation, Functions 1 and 2. and ESFAS Function 2. Containment for all initiation functions and requirements.

Spr11y Ca) Ca) Only required in HCX>ES 1. 2. 3 and 4 as specified in LCO 3.3.2. Cb) As specified in the IP3 Offsite Dose Calculation H11nua1: INDIAN POINT 3 3.3.6*5 Amenanent 205

3.3 INSTRUMENTATION

CRVS Actuation Instrumentation 3.3.7 3.3.7 Control Room Ventilation System (CRVS) Actuation Instrumentation LCO 3.3.7 The CRVS actuation instrumentation for each Function in Table 3.3.7-1 shall be OPERABLE.

APPLICABILITY:

MODES l, 2, 3, 4 ACTIONS ------------------------------------NOTE---------------------------------

Separate Condition entry is allowed for each Function.

COMPLETION REQUIRED ACTION TIME CONDITION A. One or more A. l Place CRVS in CRVS 7 days Functions with one Mode 3. channel or train inoperable.

B. One or more B .1.1 Place CRVS in CRVS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Functions with two Mode 3. channels or two trains inoperable.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for AND --Condition A or B not -----NOTE --------met. LCO 3.0.4.a is not applicable when entering MODE 4. -------------------

C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> INDIAN POINT 3 3.3.7 -1 Amendment 252 u CRVS Actuation Instrumentation

3.3.7 SURVEILLANCE

REQUIREMENTS

• • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • NOTE*********************************************

Refer to Table 3.3.7-1 to determine which SRs apply for each CRVS Actuation Function.

SURVEILLANCE SR 3.3.7.1 Perform actuation logic test

• SR 3.3. 7 .2 **********************NOTE*********************

Verification of setpoint is not required.

Perform TADOT. INDIAN POINT 3 3.3.7*2 FREQUENCY 31 days staggered test basis 24 months Menanent 205 u u FUNCTION 1. Hanual Initiation

2. Automatic Actuation Logic and Actuation Relays 3. Safety Injection INDIAN POINT 3 CRVS Actuation Instrumentation

3.3.7 Table

3.3.7*1 (page 1 of 1) CRVS Actuation Instr1.111entation REQUIRED CHANNELS 2 2 trains sm.VEILL.ANCE REQUIREMENTS SR 3.3.7.2 SR 3.3.7.1 TRIP SETPOINT NA NA Refer to LCO 3.3.2. *EsFAS Instr1.111entation.*

Function 1. for all initiation functions and requirements.

3.3.7*3 Mlenanent 205 V V u 3.3 INSTRUMENTATION FSBEVS Action Instrumentation 3.3.8 3.3.8 Fuel Storage Building Emergency Ventilation System (FSBEVS) Actuation Instrumentation LCO 3.3.8 FSBEVS manual and automatic actuation instrumentation shall be OPERABLE.

APPLICABILITY:

During movement of recently irradiated fuel in the fuel storage building.

ACTIONS CONDITION A Manual or automatic A.1 FSBEVS actuation instrumentation inoperable.

INDIAN POINT 3 OR A.2 REQUIRED ACTION Place FSBEVS in operation.

COMPLETION TIME Immediately Suspend movement of Immediately recently irradiated fuel in the fuel storage building.

3.3.8-1 Amendment 215 MAR 17 2003 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.8.1 Perform CHANNEL CHECK. SR 3.3.8.2 Perform COT. SR 3.3.8.3 Perform CHANNEL CALIBRATION.

INDIAN POINT 3 3.3.8*2 FSBEVS Actuation Instrumentation

3.3.8 FREQUENCY

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 92 days 24 months Amendment 205 u u u RCS Pressure, Temperature, and Flow Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS ~ressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the .limits specified below: a. Pressurizer pressure is greater than or equal to the limit specified in the COLR; b. RCS average loop temperature is less than or equal to the limit specified in the COLR; and c. RCS total flow rate~ 354,400 gpm and greater than or equal to the limit specified in the COLR. APPLICABILITY:

MODE.l. ------------------------------NOTE------------------------

Pressurizer pressure limit does not apply during: a. THERMAL POWER ramp> 5% RTP per minute; or b. THERMAL POWER step> 10% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS A.l Restore.RCS DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> DNB parameters not parameter(s) to within limits. within limits. B. Required action and B. l Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. INDIAN POINT 3 3.4.1-1 Amendment 225 u u u RCS Pressure, Temperature, and Flow Limits 3.4.1 SURVEILLANCE REQUIREMENTS

,.. . SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is greater 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> than or equal to the limit specified in the COLR. SR 3.4.1.2 Verify RCS average loop temperature is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> less than *or equal to the limit specified in the COLR. SR 3.4.1.3 Verify RCS total flow rate is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3. 4 .1. 4 INDIAN POINT 3 354,400 gpm and greater than or equal to the limit specified in the COLR. -------------------NOTE----------------

Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after~ 90% RTP. Verify by precision heat balance that RCS total flow rate is~ 354,400 gprn and greater than or equal to the limit specified in the COLR. 3.4.1-2 24 months Amendment 225 u u RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Hinimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature CTavg> shall be 2: 540°F. APPLICABILITY:

HOOE 1, MODE 2 with kett 2: 1. 0. ACTIONS A. CONDITION Tavg in one or more A.1 RCS loops not within limit. SURVEILLANCE REQUIREHENTS SURVEILLANCE REQUIRED ACTION Be in HODE 2 with kett < 1.0. SR 3.4.2.1 Verify RCS Tavg in each loop 2: 540°F. INDIAN POINT 3 3.4.2-1 COMPLETION TI HE 30 minutes FREQUENCY

---

NOTE------

Only required if Tavg -T ref deviation, and low Tavg alarm not reset and any RCS loop Tavg < 547°F 30 minutes thereafter Amendment 205

3.4 REACTOR

COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (PIT) Limits RCS P/T Limits 3.4.3 LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in Figure 3.4.3-1 and Figure 3.4.3-2. APPLICABILITY:

At all times. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE---------

A.1 Restore parameter(s) to 30 minutes Required Action A.2 shall within limits. be completed whenever this Condition is entered. AND ----------------------

A.2 Determine RCS is 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Requirements of LCO not acceptable for continued met in MODE 1, 2, 3, or operation.

4. B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not AND met. 8.2 Be in MODE 5 with RCS 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> pressure<

500 psig. ( continued)

INDIAN POINT 3 3.4.3-1 Amendment 258 ACTIONS (continued)

CONDITION REQUIRED ACTION C. ---------NOTE----------------

C.1 Initiate action to restore Required Action C.2 shall parameter(s) be completed whenever to within limits. this Condition is entered. ---------------------------------

AND Requirements of LCO not C.2 Determine RCS is met any time in other acceptable for continued than MODE 1, 2, 3, or 4. operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.3.1 -------------------NOTE--------------

INDIAN POINT 3 Only required to be performed during RCS heatup, inservice leak testing, and cooldown operations.

Verify RCS pressure, RCS temperature, and RCS heatup and cooldown rates are within the limits specified in the following:

a. Figure 3.4.3-1 during RCS heatup and during RCS inservice leak testing; and b. Figure 3.4.3-2 during RCS cooldown.

3.4.3-2 RCS P/T Limits 3.4.3 COMPLETION TIME Immediately Prior to entering MODE 4 FREQUENCY 30 minutes Amendment 258 RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL:

Lower Shell Plate B-2803-3 using credible surveillance data, Position 2.1 LIMITING ART VALUES AT 37 EFPY: 1/4T, 245.0°F (Axial Flaw) 3/4T, 198.2°F (Axial Flaw) -ct VJ C. -2250 ! 2000 ::s U) U) ! C. E 1750 U) >. VJ ! 1500 0 0 0 ... 1250 ns 1000 750 500 250 I jLeak Test Limit t-+ Acceptable Operation 0 50 100 150 200 250 300 350 400 450 500 550 T cold Temperature (Deg. F) Figure 3.4.3-1: Heatup and lnservice Leak Test Limitations for Reactor Coolant System (Without instrument uncertainties)

INDIAN POINT 3 3.4.3-3 Amendment 258 MATERIAL PROPERTY BASIS RCS P/T Limits 3.4.3 LIMITING MATERIAL:

Lower Shell Plate B-2803-3 using credible surveillance data, Position 2.1 LIMITING ART VALUES AT 37 EFPY: 1/4T, 245.0°F (Axial Flaw) 3/4T, 198.2°F (Axial Flaw) 2250 <2000 en a. -Q) :5 1750 Ill Ill a. 1500 -Ill >, en -; 1250 0 0 (.) ... 0 u 1000 cu Q) 0::: 750 500 250 INDIAN POINT 3 Unacceptable Operation ates eg. F/Hr teady -state 20 0 60 100 Acceptable Operation 0 50 100 150 200 250 300 350 400 450 500 550 T cold Temperature (Deg. F) Figure 3.4.3-2: Cooldown Limitations for Reactor Coolant System (Without instrument uncertainties) 3.4.3-4 Amendment 258 u V 3.4 REACTOR COOL.ANT SYSTEH (RCS) 3.4.4 RCS Loops -HODES 1 and 2 RCS Loops -HODES 1 and 2 3.4.4 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY:

HODES 1 and 2. ACTIONS CONDITION A. Req*ui rements of LCO not met.* SURVEILLANCE REQUIREMENTS A.1 SURVEILLANCE REQUIRED ACTION Be in HODE 3. SR 3.4.4.1 Verify each RCS loop is in-operation.

INDIAN POINT 3 3.4.4-1 COMPLETION TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> , Amenanent 205 u RCS Loops -HOOE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops-HOOE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and either: a. Two RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal:

or b. One RCS loop shall be in operation when the Rod Control System is not capable of rod withdrawal.

• * * * * * * -* * * * * * ** * * * * * * * * * * * -NOTE* * * * * * * * * * -* * * * * * * * * * -* * * * * * * * * * *

• All reactor coolant pumps may not be in operation for~ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:

a. No operations are permitted that would cause reduction'of the RCS boron concentration:

and b. Core outlet temperature is maintained at least l0°F below saturation temperature.

APPLICABILITY:

HOOE 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. One required RCS loop A.1 Restore required RCS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.

loop to OPERABLE status. B. Required Action and B.1 Be in HOOE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met. (continued)

INDIAN POINT 3 3A.5*1 Amenanent 205 ACTIONS (continued)

CONDITION C. One required RCS loop C.1 not in operation, and reactor trip breakers closed and Rod Control 08 System capable of rod withdrawal.

C.2 D. Two required RCS loops D.1 inoperable.

AfiQ 08 D.2 No RCS loop in operation. . u AfiQ D.3 u INDIAN POINT 3 REQUIRED ACTION Restore required RCS loop to operation.

De-energize all control rod drive mechanisms (CRDHs). De-energize all CRDMs. Suspend all operations involving a reduction of RCS boron concentration . Initiate action to restore one RCS loop to OPERABLE status and in operation.

3.4.5-2 RCS Loops -HOOE 3 3.4.5 COMPLETION TIHE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour IRV11edi ate 1 y Immediately Immediately Amenonent 205 u SURVEILLANCE REQUIREHENTS SR 3.4.5.1 SR 3.4.5.2 SR 3.4.5.3 INDIAN POINT 3 SURVEILLANCE Verify required RCS loops are in operation.

Verify steam generator secondary side actual water levels are~ 71~ wide range for required RCS loops. Verify correct breaker alignment and indicated power are available to the required pump that is not in operation.

3.4.5*3 RCS Loops -HOOE 3 3.4.5 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours 7 days Amenanent 205 u u RCS Loops -HOOE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3 .4. 6 RCS Loops -HOOE 4 LCO 3.4.6 APPLICABILITY:

• ACTIONS Two loops consisting of any combination of RCS loops and residual heat removal CRHR) loops shall be OPERABLE.

and one loop shall be in operation.

---

*---------------------*-

NOTES*--------*------*----*--------

1. All reactor coolant pumps (RCPs) and RHR pumps may not be in operation for~ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:

a. No operat~ons are permitted that would cause reduction of the RCS boron concentration:

and b. Core outlet temperature is maintained at least l0°F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature less than the LTOP arming temperature unless the requirements of LCO 3.4.12, -Low Temperature Overpressure Protection CLTOP)." are met. ' HODE 4. CONDITION REQUIRED ACTION COMPLETION TIHE A. One required RCS loop inoperable.

Two RHR loops inoperable.

INDIAN POINT 3 A.1 Initiate action to Inrnediately restore a second loop to OPERABLE status. (continued) 3.4.6-1 Amendnent 205 ACTIONS (continued)

CONDITION B. One required RHR*loop B.1 inoperable.

MlQ Two required RCS loops inoperable.

C. Required RCS or RHR loops C.1 inoperable.

QR MlQ No RCS or RHR loop in operation.

C.2 u INDIAN POINT 3 REQUIRED ACTION Be in HOOE 5. Suspend all operations involving a reduction of RCS boron concentration.

Initiate action to restore one loop to OPERABLE status and in operation.

3.4.6*2 RCS Loops -HOOE 4 3.4.6 COHPLETION TIHE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Invnediately Invnediately Amenanent 205 u SURVEILLANCE REQUIREMENTS SR 3.4.6.1 SR 3.4.6.2 SR 3.4.6.3 INDIAN POINT 3 SURVEILLANCE Verify one RHR or RCS loop is in operation.

Verify SG secondary side water actual level is 71X wide range for each required RCS loop. Verify correct breaker alignment and indicated power are available to the required pump that is not in operation.

3.4.6*3 RCS Loops -HOOE 4 3.4.6 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours 7 days Amenctnent 205 RCS Loops -Mode 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops-MODE 5, Loops Filled LCO 3.4.7 APPLICABILITY:

INDIAN POINT 3 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either: a. One additional RHR loop shall be OPERABLE; or b. The secondary side water level of at least two steam generators (SGs) shall be~ 71% wide range. ---------------~-------------

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

1. The RHR pump of the 1 oop in operation may not be in ope rat: ion for~ I hour per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and b. Core outlet temperature is maintained at least I0°F below saturation temperature.

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

3. No reactor coolant pump shall be started with the average of the RCS cold leg temperatures~

330°F unless the requirements of LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP)," are met. 4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least on~ RCS loop is in operation.

MODE 5 with RCS loops filled. 3.4.7-1 Amendment 235 ACTIONS CONDITION A. One RHR loop inoperable.

A.1 AHO Required SGs secondary Q8 side water level not within the limit. A.2 B. Required RHR loops B.1 inoperable.

Q8 u MfQ No RHR loop in operation.

B.2 u INDIAN POINT 3 RCS Loops -HOOE 5, Loops Fi 11 ed 3.4. 7 REQUIRED ACTION COMPLETION TIME Initiate action to I11111ediately restore a second RHR loop to OPERABLE status. Initiate action to I11111ediately restore required SG secondary side water level to within the limit. Suspend all operations I11111ediately involving a reduction of RCS boron concentration.

Initiate action to I11111ediately restore one RHR loop to OPERABLE .status and in operation.

3.4. 7*2 Amenctnent 205 u u RCS Loops -HOOE 5, Loops Fi 11 ed 3.4.7 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.4.7.2 Verify SG secondary side water level is~ 71% 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> wide range in required SGs. SR 3.4.7.3 Verify correct breaker alignment and indicated 7 days power are available to the required RHR pump that is not in operation.

INDIAN POINT 3 3.4.7-3 Amenanent 205 u u RCS Loops -HOOE 5, Loops Not Fi 11 ed 3.4.8 3.4 REACTOR COOLANT SYSTEH (RCS) 3 .4. 8 RCS Loops -HOOE 5, Loops Not Fi 11 ed LCO 3.4.8 APPLICABILITY:

ACTIONS Two residual heat removal CRHR) loops shall be OPERABLE and one RHR loop shall be in operation.

• • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • NOTES******************************

1. All RHR pumps may not be in operation for s 15 minutes provided:

a. The core outlet temperature is maintained at least l0°F below saturation temperature.

b. No operations are permitted that would cause a reduction of the RCS boron concentration:

and c. No draining operations to further reduce the RCS water volume are permitted.

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

HOOE 5 with RCS loops not filled. CONDITION REQUIRED ACTION COHPLETION TI HE A. One RHR loop inoperable.

A.1 *INDIAN POINT 3 Initiate action to restore RHR loop to OPERABLE status. 3.4.8-1 IIIITlediately (continued)

Amenanent 205 ACTIONS (continued)

CONDITION B. Required RHR loops B.1 inoperable.

OR AfiQ No RHR loop in operation.

B.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS Loops -HOOE 5, Loops Not Fi 11 ed 3.4.8 REQUIRED ACTION COMPLETION TIHE Suspend all operations Invnedi ately involving.reduction in RCS boron concentration.

Initiate action to Invnediately restore one RHR loop to OPERABLE status and in operation.

FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.4.8.2 Verify correct breaker alignment and indicated 7 days power are available to the required RHR pump that is not in operation.

INDIAN POINT 3 3.4.8*2 Amencknent 205 u u u 3.4 REACTOR COOLANT SYSTEM (RCS} 3.4.9 Pressurizer Pressurizer 3.4.9 LCO 3.4.9 The pressurizer shall be OPERABLE with: a. Pressurizer water level~ 54.3% in MODES 1 and 2 or< 90% in MODE 3; and b. Two groups of pressurizer heaters OPERABLE with the capacity of.each group~ 150 kW and capable of being powered from an emergency power supply. APPLICABILITY:

MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water A.1 Be in MODE 3 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> level not within reactor trip limit. breakers open. .. ANO --A.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> B. One required group B.1 Restore required 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> of pressurizer group of heaters inoperable.

pressurizer heaters to OPERABLE status. C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of AND Condition B not met. C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> INDIAN POINT 3 3.4.9-1 Amendment 225 u u SURVEILLANCE REQUIREMENTS SR 3.4.9.1 SR 3.4.9.2 INDIAN POINT 3 SURVEILLANCE Verify pressurizer water level is 54.3% in MODES 1 and 2 OR< 90% in MODE 3. Verify capacity of each required group of pressurizer heaters is~ 150 kW. 3.4.9-2 Pressurizer

3.4.9 FREQUENCY

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 24 months Amendment 225 Pressurizer Safety Valves 3 .4.10 3.4 REACTOR COOLANT SYSTEM (RCS) .3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings set~ 2460 psig and~ 2510 psig. APP LI CAB I LI TY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures>

330°F. ------------------------------NOTE----------------------------------

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

This exception is allowed for 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> following entry into MODE 3 provided?

preliminary cold setting was made prior to heatup. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME *.*: A. One pressurizer safety A. l Restore valve to 15 minutes valve inoperable.

OPERABLE status. B. Required Action and B. l Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> RCS cold leg Two or more pressurizer temperature~

330°F. safety valves inoperable.

INDIAN POINT 3 3.4.10-1 Amendment 235 u Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SR 3.4.10.1 INDIAN POINT 3 SURVEILLANCE Verify each pressurizer safety valve is OPERABLE in accordance with the Inservice Testing Program. Following testing, lift settings shall be~ 2460 psig and~ 2510 psig. 3.4.10*2 FREQUENCY In accordance with the Inservice Testing Program Amencinent 205 u 3.4 REACTOR COOLANT SYSTEM (RCS) Pressurizer PORVs 3.4.11 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) LCO 3. 4 .11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS --------------------NOTE----------------------------

Separate Condition entry is allowed for each PORV. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable and power to capable of being associated block manually cycled. valve. B. One PORV inoperable B.l Close associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and not capable of block valve. being manually cycled. AND --B.2 Remove power from 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> associated block valve. AND --B.3 Restore PORV to 7 days OPERABLE status. (continued)

INDIAN POINT 3 3.4.11-1 Amendment 226 .,

ACTIONS (continued)

CONDITION C. One block valve C.1 inoperable.

MID C.2 D. Required Action and D.1 associated Completion Time of Condition A. B, MID or C not met. D.2 E. Two PORVs inoperable and E.1 not capable of being manually cycled. MID E.2 MID E.3 MID E.4 u INDIAfl POINT 3 REQUIRED ACTION Place associated PORV in manual control. Restore block valve to OPERABLE status. Be in HOOE 3. Be in HOOE 4. Close associated block valves. Remo_ve power from associated block valves. Be in HOOE 3.*. Be in HOOE 4. 3.4.11-2 Pressurizer PORVs 3.4.11 COMPLETION TI HE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 7 days 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours (continued)

Arnenanent 205 ACTIONS (continued)

CONDITION REQUIRED ACTION F. Hore than one block valve F.1 Place associated PORVs inoperable.

in manual control. MID F.2 Restore one block valve to OPERABLE status. G. Required Action and G.1 Be in HOOE 3. associated Completion Time of Condition F not MID met. G.2 Be in HOOE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.11.1 * * * * * * * * * * **.*******NOTE********************

SR 3.4.11.2 INDIAN POINT 3 Not required to be met with block valve closed in accordance with the Required Action of Condition B or E. Perform a complete cycle of each block valve. Perform a complete cycle of each PORV. 3.4.11*3 Pressurizer PORVs 3.4.11 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 2 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours FREQUENCY 92 days 24 months

• Amencinent 205 LTOP 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (L TOP) LCO 3.4.12 L TOP shall be OPERABLE with no high head safety injection (HHSI) pumps capable of injecting into the RCS and the accumulator discharge isolation valves closed and de-energized, and either of the following:

--~-----------------------------Note--------------------

LCO 3.4.12.a and LCO 3.4.12.b are not Applicable when all RCS cold leg temperatures are > 330°F. a. The Overpressure Protection System (OPS) OPERABLE with two power operated relief valves (PORVs) with lift settings within the limit specified in Figure 3.4.12-1; OR b. The RCS depressurized with an RCS vent of~ 2.00 square inches, or one blocked open PORV with its block valve disabled in the open position.

---

~-------------~--------NOTES-----------------------

1. Accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the coldest existing RCS cold leg temperature allowed by the Prr limit curve in Figure 3.4.12-1.

2. One HHSI pump may be made capable of injecting into the RCS as needed to support emergency boration or to respond to a loss of RHR cooling. 3. One HHSI pump may be made capable of injecting into the RCS for pump testing for a period not to exceed 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. APPLICABILITY:

Whenever the RHR System is not isolated from the RCS, MODE 4 when any RCS cold leg temperature is s 330°F, MODE 5, MODE 6 when the reactor vessel head is on. INDIAN POINT 3 3.4.12 1 Amendment 258 ACTIONS --------------------NOTE:--------------------------------------------

LCO 3.0.4.b is not applicable when entering MODE: 4. CONDITION A. One or more HHSI pump(s) capable of injecting into the RCS. INDIAN POINT 3 RE:QUIRE:D ACTION A.1 Initiate action to verify no HHSI pumps are capable of injecting into the RCS. OR A.2.1 Verify RCS is vented with opening greater than or equal to one pressurizer code safety valve flange. AND A.2.2 Verify no more than two HHSI pumps are capable of injecting into the RCS 3.4.12-2 LTOP 3.4.12 COMPLE:TION TIME: Immediately Immediately Immediately AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ( continued)

Amendment 258 LTOP 3. 4 .12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 8. .An accumulator B .1 Close and de-energize 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> discharge isolation isolation valve for valve not closed and affected accumulator.

de-energized when the accumulator pressure is greater than or equal to the maximum RCS pressure for the coldest existing cold ' leg temperature specified in Figure 3.4.12-1.

C. Required Action and C.1.1 Increase all RCS cold 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion leg temperatures to Time of Condition B not > 330°F. met. AND c.1.2 Isolate the RHR System 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from the RCS. OR C.2 Depressurize affected 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> e accumulator to less than the maximum RCS pressure for coldest existing cold leg temperature specified in Figure 3.4.12-1.

D. One required PORV D.l Restore required PORV 7 days inoperable.

to OPERABLE status. (continued)

I ND IAN PO INT 3 3.4.12-3 Amendment 235 A CTIONS (continued)

CONDITION E. Two required PORVs inoperable.

OR Required Action and associated Completion Time of Condition C or D not met. F. L TOP inoperable for any reason other than Condition A, B, C, D, or E. INDIAN POINT 3 REQUIRED ACTION E.1 Depressurize RCS and establish RCS vent of ::::: 2.00 square inches, or one blocked open PORV with its block valve disabled in the open position.

OR E.2.1 Increase all RCS cold leg temperatures to > 330°F. AND E.2.2 Isolate the RHR System from the RCS. OR E.3 Verify pressurizer level, RCS pressure, and RCS injection capability are within limits specified in Figure 3.4.12-2 and Figure 3.4.12-3 for OPS not OPERABLE.

F.1 Depressurize RCS and establish RCS vent of ::::: 2.00 square inches, or one blocked open PORV with its block valve disabled in the open position.

3.4.12-4 LTOP 3.4.12 COMPLETION TIME 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 8 hours 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 8 hours AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Amendment 258 SURVEILLANCE REQUIREMENTS SR 3.4.12.1 SR 3.4.12.2 SURVEILLANCE Verify no HHSI pumps are capable of injecting into the RCS. Verify each accumulator discharge isolation valve is closed and de-energized; OR LTOP 3.4.12 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours Verify each accumulator pressure is less than the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.4.12.3 INDIAN POINT 3 maximum RCS pressure for the coldest existing RCS cold leg temperature allowed by the Prr limit curve in Figure 3.4.12-1.

---

NOTE-----------------------------~------~-

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

Verify RCS vent 2 2.00 square inches, or one blocked open PORV with its block valve disabled in the open position established.

3.4.12-5 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for unlocked open vent valve(s) 31 days for locked open vent valve( s) ( continued)

Amendment 258 SURVEILLANCE REQUIREMENTS (continued)

SR 3.4.12.4 SR 3.4.12.5 SR 3.4.12.6 SR 3.4.12.7 INDIAN POINT 3 SURVEILLANCE

---

NOTE--.-----------------

Only required to be met when complying with LCO 3.4.12.a.

Perform CHANNEL CHECK of Overpressure Protection (OPS) instrument channels.

Verify PORV block valve is open for each required PORV. --------------------NOTE------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after decreasing any RCS cold leg temperature to :::; 330°F. Perform a COT on each required PORV, excluding*

actuation.

Perform CHANNEL CALIBRATION for each required OPS channel as follows: a. OPS actuation channels; and b. RCS pressure and temperature instruments.

3.4.12-6 LTOP 3 .4.12 FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 72 hours 24 months 18 months 24 months (continued)

Amendment 235 SURVEILLANCE REQUIREMENTS (continued}

SR 3.4.12.8 INDIAN POINT 3 SURVEILLANCE

---

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

1. Not required to be met when all RCS cold leg temperatures are> 330°F. 2. Not required to be met if SR 3.4.12.9 is met. Verify each of the following conditions are satisfied prior to starting any RCP: a. Secondary side water temperature of the hottest steam generator (SG) is less than or equal to the coldest RCS cold leg temperature; and b. RCS makeup is less than or equal to RCS 1 osses; and c. Steam generator pressure is not decreasing; and d.l Overpressure Protection System (OPS) is OPERABLE; d.2~1 RCS pressure less than nominal OPS setpoint specified in Figure 3.4.12-1; and d.2.2 Pressurizer level, RCS pressure, and RCS injection capability are within limits specified in Figure 3.4.12-2 and Figure 3.4.12-3 for OPS not OPERABLE.

3.4.12-7 LTOP 3. 4.12 FREQUENCY Within 15 minutes prior to starting any RCP (continued)

Amendment 235 SURVEILLANCE REQUIREMENTS continued SR 3.4.12.9 Indian Point 3 SURVEILLANCE

---

NO TES----------------

1. Not required to be met when all RCS cold leg temperatures are> 330°F. 2. Not required to be met if SR 3.4.12.8 is met. Verify each of the following conditions are satisfied prior to starting any RCP: a. Secondary side water temperature of the hottest steam generator is ::;; 50°F above the coldest RCS cold leg temperature; and b. RCS makeup is less than or equal to RCS losses; and c. Overpressure Protection System (OPS) is OPERABLE; and d. Pressurizer level is ::;; 73%. 3.4.12-8 FREQUENCY Within 15 minutes prior to starting any RCP Amendment 258 INDIAN POINT 3 "" Q. 800 750 ::' 700 .5 :., ::r. 650 -'"" ::;.. :., 1600 -= < ... .. ::: E 550 X :1 500 450

• 50 100 150 200 250 300 Auctioneered Low Indicated RCS Temperature (0 F) Figure 3.4.12-1:

Maximum Allowable PORV Setpoint for LTOP (OPS), 37 EFPY 350 3.4.12-9 Amendment 258 LTOP 3.4.12 100 90 ;i 80 !-, 1> 70 ] ... Cl 60 *~ :, .. .. 50 Cl .. !::.. .S! 40 i 0 ::::i 30 < ,< ;;;; 20 ' JO 0 0 ::; 300 psig s 400 psig s 450psig 50 100 150 200 Indicated Tcold (0 F) 250 300 350 400 LTOP 3.4.12 3.4.12-2:

Maximum Allowable Pres zer Level for LTOPS Inoperable with 1 Charging Pump Capable of Injecting, 37 EFPY INDIAN POINT 3 3.4.12-10 Amendment 258 90 so

• s 100 psig s 200 psig 10 0 0 50 100 l:nacceptable Operation 150 200 Indicated Tcold (°f) 250 300 350 400 LTOP 3.4.12 Figure 3.4.12-3:

Maximum Allowable Pressurizer Level for LTOPS Inoperable with 3 Charging Pumps Capable of Injecting, 37 EFPY INDIAN POINT 3 3.4.12-11 Amendment 258 RCS Operational Leakage 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to: a. No pressure boundary LEAKAGE; b. 1 gpm unidentified LEAKAGE; c. 10 gpm identified LEAKAGE; and d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG). APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> LEAKAGE not within within limits. limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE. B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of AND Condition A not -----NOTE -------met. LCO 3.0.4.a is not applicable when OR entering MODE 4. ------Pressure boundary LEAKAGE exists. B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR Primary to secondary LEAKAGE not within limit. INDIAN POINT 3 3.4.13-1 Amendment 252 RCS Operational Leakage 3.4.13 SURVEILLANCE REQUIREMENTS SR 3.4.13.1 SR 3.4.13.2 INDIAN POINT 3 SURVEILLANCE

---

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

1. Not required to be performed in MODE 3 or 4 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of steady state operation.

2. Not applicable to primary to secondary LEAKAGE. Verify RCS Operational LEAKAGE is within limits by performance of RCS water inventory balance. -------------------NOTE-----------------------

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

Verify primary to secondary LEAKAGE is< 150 gallons per day through any one SG. 3.4.13-2 \ FREQUENCY Only required to be performed during steady state operation 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours Amendment 233 u u 3.4 REACTOR COOLANT SYSTEH (RCS) 3.4.14 RCS Pressure Isolation Valve CPIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit: RCS PIV Leakage 3.4.14 The RHR System autoclosure interlocks CACI) and open permissive interlocks COPI) shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, and 3, HOOE 4, except for leakage limits for valves in the residual heat removal CRHR) flow path when in, or during the transition to or from. the RHR mode of operation

.. ACTIONS **************************************

NOTES***************************************

1. Separate Condition entry is allowed for each flow path. 2. Separate Condition entry is allowed for each ACI and OPI. 3. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV. CONDITION A. One or more flow paths with leakage from one or more RCS PIVs not within limit. INDIAN POINT 3 REQUIRED ACTION **************NOTE**************

Each valve used to satisfy Required Action A.1 and Required Action A.2 must have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system. 3.4.14*1 COMPLETION TI HE (continued)

Amenanent 205 RCS PIV 3.4.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.1 Isolate the high 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> pressure portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve. AND --A.2.1 Isolate the high 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> pressure portion of the affected system from the low-pressure portion by use of a second closed manual, deactivated automatic, or check valve. OR A.2.2 Restore RCS PIV to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> within limits. B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for AND --Condition A not -----NOTE ------met. LCO 3.0.4.a is not applicable when entering MODE 4. ----------

---

B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)

INDIAN POINT 3 3.4.14-2 Amendment 252

---

*---*

u u \__) . ACTIONS (continued)

C. CONDITION One or more RHR System autoclosure interlocks or open permissive interlocks inoperable.

INDIAN POINT 3 REQUIRED ACT! ON **************NOTE**************

RHR System suction isolation valves with inoperable ACis or OPis may be opened for 7 days following entry into MODE 4 from MODE 3. C.1 Close and de-activate the affected RHR isolation valve. MID C.2 Verify the affected RHR isolation valves are closed and de-activated.

3.4.14*3 RCS PIV Leakage 3.4.14 COMPLETION TI HE 7 days Once per 31 days thereafter Amenanent 205 u

• SURVEILLANCE REQUIREMENTS SR 3.4.14.1 INDIAN POINT 3 SURVEILLANCE

---

*------**NOTES------*--------------

1. Not required to be performed in HODES 3 and 4. 2. Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided. Verify leakage from each RCS PIV is equivalent to 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure~

2215 psig and~ 2255 *psig. 3.4.14-4 RCS PIV Leakage 3.4.14 FREQUENCY 24 months Prior to entering HOOE 2 whenever the unit has been in HOOE 5 for 7 days or more. if leakage testing has not been performed in the previous 12 months Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following valve actuation due to* automatic or manual action or flow through the valve (continued)

Amendnent 205 u SURVEILLANCE REQUIREMENTS (continued)

SR 3.4.14.2 SR 3.4.14.3 INDIAN POINT 3 SURVEILLANCE Verify RHR System open permissive interlock prevents the valves from being opened with a simulated or actual RCS pressure signal ::i: 450 psig. Verify RHR System autoclosure interlock causes the valves to close automatically with a simulated or actual RCS pressure signal ::i: 550 psig. 3.4.14*5 RCS PIV Leakage 3.4.14 FREQUENCY 24 months 24 months Amenanent 205 u ., RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump discharge flow monitor; b. One containment atmosphere radioactivity monitor (gaseous or particulate);

and c. One containment fan cooler unit condensate measuring system. APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION A. Required containment sump flow monitor inoperable.

INDIAN POINT 3 t -.--., A. l AND A.2 REQUIRED ACTION Perform SR 3.4.13.1.

Restore required containment sump monitor to OPERABLE status. 3.4.15-1 COMPLETION TIME Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 30 days (continued)

Amendment 226 ACTIONS (continued)

CONDITION B. Required containment B.1.1 atmosphere radioactivity monitor inoperable.

DR B.1.2 AHO B.2.1 , u DR B.2.2 C. Required containment C.l fan cooler unit condensate measuring DR system inoperable.

C.2 INDIAN POINT 3 RCS Leakage Detection Instrumentation 3.4.15 REQUIRED ACTION CO HP LET ION TI HE Analyze grab samples of Once per the containment 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> atmosphere.

Perform SR 3.4.13.1.

Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Restore required 30 days containment atmosphere radioactivity monitor to OPERABLE status. Verify containment 30 days fan cooler unit condensate measuring system is OPERABLE.

Perform SR 3.4.15.1.

Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Perform SR 3.4.13.1.

Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> (continued) 3.4.15*2 Amenanent 205 ACTIONS (continued)

RCS Leakage Detection Instrumentation 3.4.15 CONDITION REQUIRED ACTION COMPLETION TIME D. Required containment D.1 E. F. atmosphere radioactivity monitor inoperable.

AND Required containment fan cooler unit condensate measuring system inoperable.

Required Action and associated Completion Time not met. All required monitors inoperable.

INDIAN POINT 3 OR D.2 E.l AND --E.2 F .1 3. 4 .15 Restore required 30 days containment atmosphere radioactivity monitor to OPERABLE status. Restore required 30 days containment fan cooler unit condensate measuring system to OPERABLE status. Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> -----NOTE -----LCO 3.0.4.a is not applicable when entering MODE 4. --------------

Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Enter LCO 3.0.3. Immediately 3 Amendment 252 u u RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS

• SR 3.4.15.1 SR 3.4.15.2 SR 3.4.15.3 SR 3.4.15.4 SR 3.4.15.5 INDIAN POINT 3 SURVEILLANCE FREQUENCY Perform CHANNEL CHECK of the required containment 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> atmosphere radioactivity monitor. Perform COT of the required containment 92 days atmosphere radioactivity monitor. Perform CHANNEL CALIBRATION of the required 24 months containment sump flow monitor. Perform CHANNEL CALIBRATION of the required 24 months containment atmosphere radioactivity monitor. Perform CHANNEL CALIBRATION of the required containment fan cooler unit condensate measuring system.

• 3.4.15-4 24 months Amencinent 205 RCS Specific Activity 3.4.16 3. 4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 RCS DOSE EQUIVALENT I-131 and DOSE EQUIVALENT XE-133 specific activity shall be within limits. APPLICABILITY:

MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVJ\.LENT

---

NOTE --------I-131 not within LCO 3.0.4.c is applicable limit. ------------------------

P. ** 1 Verify DOSE Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> EQUIVALENT I-131 < 60.0 µCi/gm. -AND --A.2 Restore DOSE EQUIVALENT I-131 to within limit. 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> B. DOSE EQUIVALENT

---

NOTE --------48 hours XE-133 not within LCO 3.0.4.c is applicable limit. ------------------------

B.l Restore DOSE EQUIVALENT XE-133 within limit. (continued)

INDIAN POINT 3 3.4.16-1 Amendment 237

., RCS Specific Activity 3.4.16 .

• ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C, Required Action and I C .1 associated Be in MODE 3 with Tavg < 500°F. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Completion Time of Condition A or B not met. OR AND DOSE EQUIVALENT C.2 Be in MODE 5 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> I-131 > 60.0 µCi/gm. SURVEILLANCE REQUIREMENTS "SURVEILLANCE SR 3.4.16.1 -------------------NOTE----------------

Only required to be rerformed in MODE 1. Verify reactor coolant DOSE EQUIVALENT XE-133 specific activity~

652 µCi/gm. SR 3.4.16.2

\ Only required to be performed in MODE 1. INDIAN POINT 3 Verify reactor coolant DOSE EQµIVALENT I-131 specific activity~

1.0 µCi/gm. 3.4.16-2 FREQUENCY 7 days 14 days AND Between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after a THERMAL POWER change of~ 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Amendment

'237

3.4 REACTOR

COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.

SG Tube Integrity 3.4.17 All SG tubes satisfying the tube plugging criteria shall be plugged in accordance with the Steam Generator Program. APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS -----------------------------------------NO TE----------------------------------------

Se pa rate Condition entry is allowed for each SG tube. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes A.1 Verify tube integrity of the 7 days satisfying the tube affected tube(s) is plugging criteria and not maintained until the next plugged in accordance refueling outage or SG with the Steam tube inspection.

Generator Program. AND A.2 Plug the affected tube(s) in Prior to entering accordance with the Steam MODE 4 following the Generator Program. next refueling outage or SG tube inspection B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not met. AND OR B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SG tube integrity not maintained.

INDIAN POINT 3 3.4.17-1 Amendment No. 257 SURVEILLANCE REQUIREMENTS SR 3.4.17.1 SR 3.4.17.2 INDIAN POINT 3 SURVEILLANCE Verify SG tube integrity in accordance with the Steam Generator Program. Verify that each inspected SG tube that satisfies the tube plugging criteria is plugged in accordance with the Steam Generator Program. 3.4.17-2 SG Tube Integrity 3.4.17 FREQUENCY In accordance with the Steam Generator Program Prior to entering MODE 4 following a SG tube inspection Amendment No. 257 u V Accumulators 3.5.1 3 . 5 EMERGENCY CORE CO OU NG SYSTEMS C ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2. MODE 3 with reactor coolant system pressure > 1000 psig. * * * * * * * * * * * * * * * * * * * * * * * * *NOTES* * * * * * * * * * * * * * * * * * * * * * * * -* * * * * * * -* ** 1. In MODE 3, all accumulator discharge isolation valves may be closed and energized for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> during the performance of reactor coolant sys tern hydrostatic testing. 2. In MODE 3, one accumulator discharge isolation valve may be closed and energized for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for accumulator check valve leakage testing. ACTIONS --CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A.1 Restore boron 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable due to concentration to boron concentration within limits of not within limits of SR 3.5.1.4. SR 3.5.1.4. B. One accumulator B.1 Restore accumulator to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable for OPERABLE status. reasons other than Condition A. (continued) INDIAN POINT 3 3.5.1-1 Amendment 222 ACTIONS {continued)

CONDITION C. Required Action and associated Completion Time of Condition A or B not met. D. Two or more accumulators inoperable.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION C.1 Be in HOOE 3. Mm C.2 Reduce reactor coolant system pressure to 1000 psig. 0.1 Enter LCO 3.0.3. Accumulators

3.5.1 COMPLETION

TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours Immediately SURVEILLANCE

• FREQUENCY SR 3.5.1.1 SR 3.5.1.2 SR 3.5.1.3 INDIAN POINT 3 Verify each accumulator discharge isolation valve 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is fully open. Verify borated water volume in each accumulator 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is~ 775 cubic feet and~ 815 cubic feet. Verify nitrogen cover pressure in each 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> accumulator is~ 600 psig and~ 700 psig. (continued) 3.5.1-2 Amencinent 205 u Accumulators

3.5.1 SURVEILLANCE

REQUIREHENTS (continued)

SR 3.5.1.4 SR 3.5.1.5 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify boron concentration in each accumulator is 31 days 2000 ppm and~ 2600 ppm. Verify power is removed from each accumulator isolation valve operator when reactor*coolant system pressure is~ 2000 psig. 3.5.1-3 *****NOTE******

Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after each solution volume increase of 10 X of indicated level. that is not the result of addition from the refueling water storage tank 31 days Amenanent 205 u 3.5 EMERGENCY CORE COOLING SYSTEHS CECCS) 3.5.2 ECCS-Operating LCO 3.5.2 Three ECCS trains shall be OPERABLE.

ECCS -Operating 3.5.2 *****************************NOTES***********************************

APPLICABILITY:

ACTIONS 1. In HOOE 3. both HHSI flow paths may be isolated by closing the isolation valves for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to perform pressure isolation valve testing per SR 3.4.14.1.

2. Operation in HOOE 3 with HHSI pumps made incapable of injecting pursuant to LCO 3.4.12. "Low Temperature Overpressure Protection CLTOP)." is allowed for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or until the temperature of all RCS cold legs exceeds 375°F, whichever comes first. HODES 1. 2. and 3. CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more trains inoperable.

Two HHSI pumps. one RHR pump and one Containment Recirculation pump are OPERABLE.

INDIAN POINT 3 A.l Restore trainCs) to OPERABLE status. 3.5.2*1 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (continued)

Amenanent 205

\__) u ACTIONS (continued)

B. CONDITION Required Action and associated Completion Time not met. REQUIRED ACTION B.1 Be in HOOE 3. B.2 Be in HOOE 4. SURVEILLANCE REQUIREHENTS SURVEILLANCE SR 3.5.2.1 Verify the following valves are in the listed position with power to the valve operator removed. Number: EQSl:tlQO FunctjQn SI-856B Closed HHSI Loop 33 Hot Leg

• Injection Stop Valve SI-856G Closed HHSI Loop 31 Hot Leg Injection Stop Valve SI-1810 Open RWST outlet isolation AC-744 Open Conrnon discharge isolation for RHR pumps SI-882 Open COC1111on RWST suction isolation for RHR pumps SI-842 Open HHSI pump minimum flow line isolation SI *843 Open HHSI pump minimum flow line isolation SI-883 Closed RHR pump return to RWST isolation AC-1870 Open RHR pump minimum flow line isolation AC-743 Open RHR pump mini mum fl ow line isolation INDIAN POINT 3 3.5.2*2 ECCS -Operating

3.5.2 COHPLETION

TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)

Amendment 205

---**--~~-

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.5.2.2 Verify that each ECCS manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify each ECCS pump's developed head at the test flow point is greater than or equal to the required developed head. SR 3.5.2.4 Verify each ECCS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. SR 3.5.2.5 Verify each ECCS pump starts automatically on an actual or simulated actuation signal. SR 3.5.2.6 Verify, for each ECCS throttle valve listed below, each position stop is in the correct position.

Valve Numbers SI-856B SI-856G SI-2165 SI-2170 SI-856C SI-856H SI-2166 SI-2171 SI-856D SI-856J SI-2168 SI-2172 SI-856E SI-856K SI-2169 INDIAN POINT 3 3.5.2-3 ECCS -Operating

3.5.2 FREQUENCY

31 days In accordance with the Inservice Testing Program 24 months 24 months 24 months (continued)

Amendment230 u SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE ECCS-Operating

3.5.2 FREQUENCY

SR 3.5.2.7 Verify, by visual inspection, each ECCS train 24 months containment sump suction inlet and recirculation sump suction inlet is not restricted bY. debris and the suction inlet screens show no evidence of structural distress or abnormal corrosion.

INDIAN POINT 3 3.5.2*4 Amenanent 205

3.5 EMERGENCY

CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS-Shutdown ECCS Shutdown 3.5.3 LCO 3.5.3 Two ECCS High Head Safety Injection (HHSI) subsystems and one ECCS Residual Heat Removal (RHR) subsystem shall be OPERABLE.

---

---

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

---

An RHR subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned to the ECCS mode of operation.

APPLICABILITY:

MODE 4. ACTIONS ----------------

---

NOTE--

LCO 3.0.4.b is not applicable to the ECCS High Head Safety Injection subsystems.

CONDITION A. Required ECCS Subsystem inoperable.

INDIAN POINT 3 A.l REQUIRED ACTION LCO 3.0.4.a is not applicable when entering MODE 4. Initiate action to restore required ECCS subsystem to OPERABLE status. 3.5.3 -1 COMPLETION TIME Immediately Amendment 252 u SURVEILLANCE REQUIREHENTS SR 3.5.3.1 INDIAN POINT 3 SURVEILLANCE The following SRs are applicable for all equipment required to be OPERABLE:

SR 3.5.2.3 SR 3.5.2.7 3.5.3-2 ECCS -Shutdown 3.5.3 FREQUENCY In accordance with applicable SRs . Amendnent 205

3.5 EMERGENCY

CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST) RWST 3.5.4 LCO 3.5.4 The RWST and two channels of RWST low level alarm shall be OPERABLE.

NOTE 1 The RWST isolation valves connected to non-safety related piping may be opened under administrative controls for up to 14 days per fuel cycle for filtration until the end of refuel outage 18. APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION A. RWST boron concentration not within limits of SR 3.5.4.3. OR RWST borated water temperature not within limits of SR 3.5.4.1. A.1 B. One channel of RWST B.l low level alarm inoperable.

C. RWST inoperable for C.1 reasons other than Condition A or B. D. Required Action and D.1 associated Completion Time not AND --met. D.2 REQUIRED ACTION Restore RWST to OPERABLE status. Restore RWST low level alarm to OPERABLE status. Restore RWST to OPERABLE status. Be in MODE 3. -----NOTE ---LCO 3.0.4.a is not applicable when entering MODE 4. Be in MODE 4. INDIAN POINT 3 3.5.4 1 COMPLETION TIME 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 7 days 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Amendment 252 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.4.1 ------------------N()TE---------------------------------

Not required to be performed when ambient air temperature is .::: 35°F and 95°F if heating steam supply isolation valves are locked closed. ------------------------------------------------------------

Verify RWST borated water temperature is 2 35°F and 105°F. SR 3.5.4.2 Verify RWST borated water level is 2 35.4 feet. SR 3.5.4.3 Verify RWST boron concentration is 2 2400 ppm and 2600 ppm. SR 3.5.4.4 Perform CHANNEL CHECK of RWST level SR 3.5.4.5 Perform CHANNEL CALIBRATl()N of RWST level switch and ensure the low level alarm setpoint is 210.5 feet and s12.5 feet. SR 3.5.4.6 Perform CHANNEL CALIBRATl()N of RWST level transmitter and ensure the low level alarm setpoint is 210.5 feet and ~12.5 feet. INDIAN P()INT 3 3.5.4-2 RWST 3.5.4 FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 7 days 31 days 7 days 184 days 18 months Amendment 253

3.6 CONTAINHENT

SYSTEHS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, 3, and 4 *. ACTIONS CONDITION REQUIRED ACTION A. Containment inoperable.

A.1 Restore containment to OPERABLE status. B. Required Action and B.1 Be -in HOOE 3. associated Completion Time not met. eHQ B.2 Be in HOOE 5. INDIAN POINT 3 3.6.1*1 Containment

3.6.1 COHPLETION

TI HE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 6 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> lwenanent 205 u SURVEILLANCE REQUIREMENTS SR 3.6.1.l INDIAN POINT 3 SURVEILLANCE Perform required visual examinations and leakage rate testing except for containment air-lock testing, in accordance with the Containment Leakage Rate Testing Program. 3.6.1*2 Containment

3.6.1 FREQUENCY

In accordance with the Containment Leakage Rate Testing Program Amenctnent 205

3.6 CONTAINMENT

SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, 3, and 4. ACTIONS Containment Air Locks 3.6.2 ****************************************NOTES*******************************************

1. Entry and exit is permissible to perform repairs on the affected air lock components.

2. Separate Condition entry is allowed for each air lock. 3. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when air lock leakage results in ex~eeding the overall containment leakage rate. CONDITION A. One or more containment air locks with one containment air lock door inoperable.

INDIAN POINT 3 REQUIRED ACTION * * * * * *******-NOTES**************

1. Required Actions A.1, A.2. and A.3 are not applicable if both doors in the same air lock are inoperable and Condition C is entered. 2. Entry and exit is*permissible for 7 days under administrative controls if both air locks are inoperable.

3.6.2*1 COMPLETION TIHE (continued)

/wendment 205 ACTIONS CONDITION A. (continued)

A.1 AMO A.2 AMO A.3 \~ INDIAN POINT 3 REQUIRED ACTION Verify the OPERABLE door is closed in the affected air lock. Lock the OPERABLE door closed in the affected air lock. ********NOTE***********

Air lock doors in high radiation areas may be verified locked closed by aaninistrative means . ...........*.*.........

Verify the OPERABLE door is locked closed in the affected *air lock. 3.6.2*2 Containment Air Locks 3.6.2 COMPLETION TIHE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 24 hours Once per 31 days (continued)

• Arnenanent 205

~* ACTIONS (continued)

CONDITION

8. One or more containment air locks with containment air lock interlock mechanism inoperable.

INDIAN POINT 3 REQUIRED ACTION -------------NOTES--------------

1. Required Actions 8.1. 8.2. and 8.3 are not applicable if both doors in the same air lock are inoperable and Condition C is entered. 2. Entry and exit of containment is permissible under the control of a dedicated i ndi vi dual. 8.1 Verify an OPERABLE door is closed in the affected air lock. AtID 8."2 Lock an OPERABLE door closed in the affected

• air lock. AtID 8.3 ---------NOTE----------

Air lock doors in high radiation areas may be verified locked closed by atininistrative means . ..***...........**.....

Verify an OPERABLE door is locked closed in the affected air lock. 3.6.2-3 Containment Air Locks 3.6.2 COMPLETION TIHE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 24 hours Once per 31 days (continued)

Amentinent 205 ACTIONS (continued)

CONDITION C. One or more containment C.1 air locks inoperable for reasons other than Condition A or B. Mm C.2 Mm C.3 D. Required Action and D.1 u associated Completion Time not met. Mm D.2 INDIAN POINT 3 REQUIRED ACTION Initiate action to evaluate overall containment leakage rate per LCO 3.6.1. Verify a door is closed in the affected air lock. Restore air lock to OPERABLE status. Be in HOOE 3. Be in HOOE 5. 3.6.2*4 Containment Air Locks 3.6.2 COMPLETION TIME Invnediately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 24 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Amenonent 205 SURVEILLANCE REQUIREHENTS SR 3.6.2.1 SR 3.6.2.2 INDIAN POINT 3 SURVEILLANCE

---

***NOTES**-*-*-***-**********

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. 2. Results shall ~e evaluated against acceptance criteria applicable to SR 3.6.1.1. Perform required air lock leakage rate testing in accordance with the Containment Leakage Rate Testing Program. Verify only one door in the air lock can be opened at a time. ' 3.6.2*5 Containment Air Locks 3.6.2 FREQUENCY In accordance with the Containment Leakage Rate Testing Program 24 months /vnenanent 205 u u 3.6 COITTAINHEITT SYSTEHS 3.6.3 Containment Isolation Valves Containment Isolation Valves 3.6.3 LCO 3.6.3 Each containment isolation valve shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, 3, and 4. ACTIONS ****************************************NOTES*******************************************

1. Penetration flow path(s) except for 36 inch purge valve 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 containment isolation valves. 4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

5. Enter applicable Conditions and Required Actions of LCO 3.6.9, "Isolation Valve Seal Water CIVSW) System," when required IVSW supply to a penetration flowpath is inoperable.

6. Enter applicable Conditions and Required Actions of LCO 3.6.10, "Weld Channel and Penetration Pressurization System CWC&PPS)," when required WC&PPS supply to a penetration flowpath is inoperable.

INDIAN POIITT 3 3.6.3*1 Amendment 205 ACTIONS (continued)

CONDITION A. * ********NOTE*********

Only applicable to penetration flow paths with two or more containment isolation valves. One or more penetration fl ow paths with one containment isolation valve inoperable, for reasons other than Condition D. INDIAN POINT 3 A.1 A.2 Containment Isolation Valves 3.6.3 REQUIRED ACTION COMPLETION TIME Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured. ********NOTE*********

Isolation devices in high radiation areas may be verified by use of administrative means. Verify the affected penetration flow path is isolated.

3.6.3*2 Once per 31 days for isolation devices outside containment Prior to entering HOOE 4 from HOOE 5 if not performed within the previous 92 days for isolation devices inside containment (continued) hnendment 205 ACTIONS (continued)

CONDITION B. ---------NOTE---------

B.1 Only applicable to penetration flow paths with two or more containment isolation valves. .....*................

One or more penetration fl ow paths with two or more containment isolation valves inoperable, for reasons other than Condition D. C. ---------NOTE---------

C.1 Only applicable to penetration flow paths with only one containment isolation valve and a closed system. *...........***.......

One or more penetration MiQ flow paths with one containment isolation C.2 valve inoperable.

u INDIAN POINT 3 Containment Isolation Valves 3.6.3 REQUIRED ACTION COMPLETION TIHE Isolate the affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange . Isolate the affected 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve. or blind flange . --------NOTE---------

Isolation devices in high radiation areas may be verified by use of acininistrative means . *......**.....*.***..

Verify the affected Once per 31 days penetration flow path is isolated. (continued) 3.6.3-3 Amencinent 205 Containment Isolation Valves 3.6.3 ACTIONS (continued}

CONDITION REQUIRED ACTION COHPLETION TIHE D. Containment bypass D.1 Restore leakage within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for leakage or limit. containment bypass hydrostatically tested leakage valve leakage not within limit. MID 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> for hydrostatically tested valve leakage E. Required Action and E.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. MID E.2 Be in HOOE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 36 inch purge supply and exhaust 31 days SR 3.6.3.2 INDIAN POINT 3 isolation valve is sealed closed. Verify each 10 inch pressure relief isolation 31 days valve is closed. except when these valves are open for pressure control. ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open. 3.6.3*4 (continued}

Mendment 205

.'-._) Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREHENTS (continued)

SR 3.6.3.3 SR 3.6.3.4 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • • NOTE**********************

Valves and blind flanges in high radiation areas may be verified by use of administrative controls.

FREQUENCY

• Verify each containment isolation manual valve 31 days and blind flange that is located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

• • • • • • • • • • • • • • • • • • • • NOTE***********************

Valves and blind flanges in high radiation areas may be verified by use of administrative means. Verify each containment isolation manual valve and blind flange that is located inside containment and not locked, sealed or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

3.6.3*5 Prior to entering HOOE 4 from HOOE 5 if not performed within the previous 92 days (continued)

Amendment 205 Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.6.3.5 Verify the isolation time of each automatic power operated containment isolation valve is within limits. SR 3.6.3.6 Verify each automatic containment isolation valve that is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. SR 3.6.3.7 Verify each 10 inch containment pressure relief line isolation valve is blocked to restrict valve opening to ::; 60 degrees. SR 3.6.3.8 Perform one complete cycle of each manually operated containment isolation valve on essential lines. SR 3.6.3.9 Verify leakage rate into containment from isolation valves sealed with service water system is within limits. INDIAN POINT 3 3.6.3-6 FREQUENCY In accordance with the lnservice Testing Program 24 months 24 months 24 months In accordance with the Containment Leakage Rate Testing Program Amendment 253

3.6 CONTAINMENT

SYSTEMS 3.6.4 Containment Pressure Containment Pressure 3.6.4 LCO 3.6.4 Containment pressure shall be maintained as follows: a. If RWST temperature is> 95°F or containment temperature is> 125°F, Containment pressure shall be 2:: -2.0 psig and :s: + 1.5 psig. b. If RWST temperature is ::::; 95°F and containment temperature is :s: 125°F, Containment pressure shall be 2:: -2.0 psig and::::; +2.5 psig. APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> not within limits. pressure to within limits. B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> INDIAN POINT 3 3.6.4-1 Amendment 253 V 3.6 CONTAINHENT SYSTEHS 3.6.5 Containment Air Temperature Containment Air Temperature 3.6.5 LCO 3.6.5 Containment average air temperature shall be> 50°F ands 130°F. APPLICABILITY:

HODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION A. Containment average air A.1 Restore containment temperature s50 °F. average air temperature to >SO °F. B. Containment average air B.1 Restore containment temperature

>130 °F. average air temperature to within d30 °F. C. Required Action and C.1 Be in HOOE 3. associated Completion Time Condition A or B MD not met. C.2 Be in HOOE 5. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.5.1 Verify containment average air temperature is within 1 imits. INDIAN POINT 3 3.6.5*1 COHPLETION TIHE Immediately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 6 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Amendment 205 Containment Spray System and Containment Fan Cooler System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray System and Containment Fan Cooler System LCO 3.6.6 Two Containment Spray trains and three Containment Fan Cooler trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment A.1 Restore 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> spray train containment spray inoperable.

train to OPERABLE AND --status. 10 days from discovery of failure to meet the LCO B. red Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not -----NOTE --met. LCO 3.0.4.a is not applicable when entering MODE 4. --------B.2 Be in MODE 4. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> (continued)

INDIAN POINT 3 3.6.6-1 Amendment 252 Containment Spray System and Containment Fan Cooler System 3.6.6 ACTIONS (continued)

CONDITION C. One containment fan C.1 cooler train inoperable.

D. Two containment fan D.1 cooler trains inoperable.

E. Required Action and E.1 associated Completion Time of AND Condition C or D not met, F. Two containment spray trains inoperable.

OR Any combination of three or more trains inoperable.

INDIAN POINT 3 E.2 F.1 REQUIRED ACTION Restore containment fan cooler train to OPERABLE status. Restore one containment fan cooler train to OPERABLE status. Be in MODE 3. ----NOTE LCO 3.0.4.a is not applicable when entering MODE 4. Be in MODE 4. Enter LCO 3.0.3. 3.6.6-2 COMPLETION TIME 7 days AND 10 days from discovery of failure to meet the LCO 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Imrnediat Amendment 252

• \_/. V Containment Spray System and Containment Fan Cooler System 3.6.6 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power 31 days operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.2 Operate each containment fan cooler unit fan for 92 days 2 15 minutes. SR 3.6.6.3 Verify each containment fan cooler unit cooling 92 days water flow rate is 2 1400 gpm. SR 3.6.6.4 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or with the equal to the required developed head. Inservice Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in 24 months the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. SR 3.6.6.6 Verify each containment spray pump starts 24 months automatically on an actual or simulated actuation signal. (continued)

INDIAN POINT 3 3.6.6-3 Arnencinent 205 V Containment Spray System and Containment Fan Cooler System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.6.7 SR 3.6.6.8 SR 3.6.6.9 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify each containment fan cooler unit starts 24 months and dampers re-position to the emergency mode automatically on an.actual or simulated actuation signal. Perform required containment fan cooler system In accordance filter testing in accordance with the Ventilation with the VFTP Filter Testing Program CVFTP). Verify each spray nozzle is unobstructed.

10 years 3.6.6-4 /wenanent 205 Recirculation pH Control System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Recirculation pH Control System LCO 3.6.7 The Recirculation pH Control System shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION A. Recirculation pH Control System inoperable.

B. Required Action and associated Completion Time not met. A. l B.1 AND --B.2 REQUIRED ACTION Restore Recirculation pH Control System to OPERABLE status. Be in MODE 3.

LCO 3.0.4.a is not icable when entering MODE 4. Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.7.1 Perform a visual inspection of eight sodium tetraborate storage baskets to verify each of the following:

INDIAN POINT 3 a. Each storage basket is in intact; and, ace and b. Collectively contain> 8096 pounds (160 cubic feet) of sodium tetraborate decahydrate, or equivalent.

3.6.7-1 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 6 hours 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> FREQUENCY 24 Months Amendment 252 u V \ 3.6 CONTAINMENT SYSTEMS 3.6.8 Not Used INDIAN POINT 3 3.6.8-1 Hydrogen Recombiners

3.6.8 Amendment

22P.

V V 3.6 CONTAINMENT SYSTEMS Isolation Valve Seal Water System 3.6.9 3.6.9 Isolation Valve Seal Water CIVSW) System LCO 3.6.9 The IVSW System shall be OPERABLE.

APPLICABILITY:

HODES 1, 2. 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One IVSW system header A.l Restore IVSW system to 7 days inoperable.

OPERABLE status. QR One IVSW automatic actuation valve. inoperable.

B. IVSW system inoperable B.1 Restore IVSW System to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for reasons other than OPERABLE Status. Condition A. C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND C.2 Be in HOOE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> , INDIAN POINT 3 3.6.9*1 Amendment 205 u Isolation Valve Seal Water System 3.6.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Verify IVSW tank pressure is~ 47 psig. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR 3.6.9.2 Verify IVSW nitrogen supply bank is pressurized 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> with: a. one cylinder with pressure~

1048 psig; or b. two cylinders with pressure~

584 psig; or C. three cylinders with pressure~

430 psig. SR 3.6.9.3 Verify the IVSW tank water volume is 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 144 gallons. SR 3.6.9.4 Verify the opening time of each air operated 24 months header injection valve is within limits. SR 3.6.9.5 Verify each automatic valve in the IVSW System 24 months actuates to the correct position on an actual or simulated actuation signal. SR 3.6.9.6 Verify the leakage rate of water from the In accordance Isolation Valve Seal Water System is within with the

• limits. Containment Leakage Rate Testing Program. INDIAN POINT 3 3.6.9*2 Amenanent 205

3.6 CONTAINHENT

SYSTEHS WC&PPS 3.6.10 3.6.10 Weld Channel and Penetration Pressurization System (WC&PPS) LCO 3.6.10 Weld Channel and Penetration Pressurization System shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, 3, and 4. ACTIONS ****************************************NOTES*******************************************

1. Separate Condition entry is allowed for each component supplied by WC&PPS. 2. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when the overall containment leakage rate acceptance criteria is exceeded.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more components A.1 Isolate the WC&PPS 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> supplied by WC&PPS not supply to the affected within the pressure limit components by use of at of SR 3.6.10.1.

least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured. (continued)

INDIAN POINT 3 3.6.10*1

• Amenanent 205

.---ACTIONS CONDITION REQUIRED ACTION A. (continued)

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

Isolation devices in high radiation areas may be verified by use of administrative means. *********************

Verify the WC&PPS supply to the affected component is isolated.

B. WC&PPS air consumption B.1 Enter applicable not within the limits of Conditions and Required SR 3.6.10.2.

Actions of LCO 3.6.3, "Containment

• Isolation Valves." Mill INDIAN POINT 3 3.6.10-2 WC&PPS 3.6.10 COMPLETION TIME Once per 31 days for i sol ati on devices outside containment not locked, sealed or otherwise secured Mill Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery that the WC&PPS air consumption 1 eakage path is depressurized and not isolated from the supported containment isolation valves (continued)

A'nendment 205 ACTIONS u CONDITION B. (continued}

8.2 MID 8.3 \_)' C. Required Action and C.1 associated Completion Time not met. MID C.2 INDIAN POINT 3 REQUIRED ACTION Enter applicable Conditions and Required Actions of LCD 3.6.2, "Containment Air Locks." ********NOTE*********

Enter condition A for components not within the pressure limit of SR 3.6.10.1.

Isolate portions of WC&PPS to restore air consumption to within limits of SR 3.6.10.2.

Be in HOOE 3. Be in HOOE 5 *. 3.6.10*3 WC&PPS 3.6.10 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery that the WC&PPS air consumption leakage path is depressurized and not isolated from the supported air lock 7 days 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours .AJnendnent 205 u SURVEILLANCE REOUIREHENTS SR 3.6.10.1 SR 3.6.10.2 SR 3.6.10.3 INDIAN POINT 3 SURVEILLANCE Verify all required portions of each WC&PPS zone is pressurized to~ 43 psig. Verify the WC&PPS air consumption is s 0.2% of the containment free volume per day. Verify the leakage rate for the WC&PPS is s 0.2X of the containment free volume per day when pressurized to~ 43 psi above containment pressure.

3.6.10*4 WC&PPS 3.6.10 FREQUENCY 31 days 31 days *****NOTE******

SR 3.0.2 is not applicable 36 months Amenanent 205 V 3.7 PI..AITT SYSTEMS 3.7.1 Hain Steam Safety Valves CHSSVs) HSSVs 3.7.1 LCO 3.7.1 The HSSVs shall be OPERABLE as specified.in Table 3.7.1-1 and Table 3.7.1-2. APPLICABILITY:

HODES 1, 2, and 3. ACTIONS ***************************************NOTE*********************************************

Separate Condition entry is allowed for each HSSV. CONDITION REQUIRED ACTION COMPLETION TI HE A. One or more required A.1 Reduce neutron flux trip 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> HSSVs inoperable.

setpoint to less than or equal to the applicable l RTP listed in Table 3.7 .l*l. B. Required Action and B.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AHO QR B.2 Be in HOOE 4. *. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> One or more steam generators with less than two HSSVs OPERABLE.

INDIAN POINT 3 3.7.1-1 Amenctnent 205 V SURVEILLANCE REQUIREMENTS SR 3. 7 .1.1 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • NOTE***********************

Only requjred to be performed in HODES 1 and 2. Verify each required HSSV lift setpoint per Table 3.7.1*2 in accordance with the Inservice Testing Program. Following testing, lift setting shall be within +/-lX. 3.7.1~2 FREQUENCY HSSVs 3.7.1 In accordance with the Inservice Testing Program Amenanent 205

\._) \._) MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1) OPERABLE Main Steam Safety Valves versus Applicable Neutron Flux Trip Setpoint in Percent of RATED THERMAL POWER MINIMUM NUMBER OF MSSVs PER STEAM GENERATOR REQUIRED OPERABLE INDIAN POINT 3 4 3 2 3.7.1-3 APPLICABLE Neutron Flux Trip Setpoint (% RTP) 57 38 20 Amendment 225 Table 3.7.1-2 (page 1 of 1) Hain Steam Safety Valve Lift Settings VALVE NUHBER STEAM GENERATOR

1. 31 #32 #33 #34 HS-45-1 HS-45*2 HS-45-3 HS*45*4 HS-46*1 HS-46*2 HS-46-3 HS-46-4 HS-47*1 HS-47*2 HS-47-3 HS-47-4 HS-48*1 HS-48*2 HS-48*3 HS-48*4 HS-49-1 HS-49*2 HS-49*3 HS-49*4 \._) INDIAN POINT 3 3.7.1*4 HSSVs 3.7.1 LIFT SITTING Cpsig +/- 3%) 1065 1080 1095 1110 1120 Amenanent 205

~* 3.7 PLANT SYSTEHS HSIVs and HSCVs 3.7.2 3.7.2 Hain Steam Isolation Valves CHSIVs) and Hain Steam Check Valves CHSCVs) LCO 3.7.2 Four HSIVs and four HSCVs shall be OPERABLE.

APPLICABILITY:

HOOE 1, HODES 2 and 3 except when all HSIVs are closed. ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. One or more HSCVs A.l Restore HSCVs to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable.

OPERABLE status. B. Required Action and B.1 Be in HOOE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A not met. B.2 Close all HSIVs. 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br /> B.3 Verify all HSIVs Once per 7 days closed. C. One HSIV inoperable in C.1 Restore HSIV to OPERABLE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> HOOE 1. status. (continued)

INDIAN POINT 3 3.7.2*1 Amencinent 205 ACTIONS {continued}

CONDITION D. Required Action and associated Completion Time of Condition C not met. E. -------*-NOTE-*---------

Separate Condition entry is allowed for each HSIV. .............**........

One or more HSIVs inoperable in HOOE 2 or 3. F. One HSIV inoperable.

ANO One or more HSCVs inoperable.

G. Required Action and associated Completion Time of Condition B, E or F not met. u INDIAN POINT 3 REQUIRED ACTION 0.1 Be in HOOE 2. E.1 Close HSIV. Mill E.2 Verify HSIV is closed. F.1 Restore all HSCVs to OPERABLE status. D.B F.2 Restore all HSIVs to OPERABLE status. G.1 Be in HOOE 3; Mill G.2 Be in HOOE 4. 3.7.2-2 HSIVs and HSCVs 3.7.2 COHPLETION TI HE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 8 hours Once per 7 days 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 8 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours Amencinent 205 HSIVs and HSCVs 3.7.2 \....__,)

SURVEILLANCE REQUIREMENTS SR 3.7.2.1 SR 3.7.2.2 INDIAN POINT 3 SURVEILLANCE FREQUENCY

---

NOTE----------**----------

Only required to be performed in HODES 1 and 2. Verify closure time of each HSIV is~ 5.0 seconds In accordance on an actual or simulated actuation signal. with the Inservice Testing Program Perform visual inspection of each HSCV. 3.7.2-3 In accordance with the Inservice Testing Program Amenanent 205

\__). 3. 7 PLANT SYSTEMS HBFPDVs, HFRVs and HF Low Flow Bypass Valves 3.7.3 3.7.3 Hain Boiler Feedpump Discharge Valves CHBFPDVs), Hain Feedwater Regulation Valves (MFRVs), Hain Feedwater Inlet Isolation Valves (HFIIVs) and Hain Feedwater (HF) Low Flow Bypass Valves LCO 3.7.3 APPLICABILITY:

ACTIONS Two MBFPDVs, four MFRVs, four HFIIVs and eight MF low flow bypass valves shall be OPERABLE.

HODES 1. 2. and 3 except when each main feedwater and bypass line is isolated by a closed and de-activated motor/air operated valve or isolated by a closed manual valve. ************************************NOTE********************************************

Separate Condition entry is allowed for each valve. CONDITION REQUIRED ACTION A. One or both MBFPDVs A.1 Close or isolate inoperable.

HBFPDV. Mill A.2 Verify HBFPOV is closed or isolated.

B. One or more HFRVs B.1 Close or isolate HFRV. inoperable.

Mill B.2 Verify HFRV is closed or isolated.

INDIAN POINT 3 3.7.3-1 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Once per 7 days 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Once per 7 days (continued)

Amendment 207 APR 1 n 2001 u ACTIONS (continued)

CONDITION C. One or more MFIIVs C.l inoperable.

AND C.2 D. One or more D.l MF low flow bypass valves inoperable.

Mill D.2 u E. Two valves in series in E.1 the same flow path inoperable.

F. Required Action and F.1 associated Completion Time not met. Mill F.2 INDIAN POINT 3 MBFPDVs, MFRVs and MF Low Flow Bypass Valves *f REQUIRED ACTION Close or isolate MFIIV. Verify MFIIV is closed or isolated.

Close or isolate bypass valve. Verify bypass valve is closed or isolated.

Isolate affected flow path. Be in MODE 3. Be in MODE 4. 3.7.3*2 3.7.3 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Once per 7 days 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Once per 7 days 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Amendment 207 /,,PR 1 :J 2CD1

---

MBFPDVs, MFRVs and MF Low Flow Bypass Valves 3.7.3 SURVEILLANCE REQUIREMENTS SR 3.7.3.1 INDIAN POINT 3 SURVEILLANCE Verify each MBFPDV, MFRV. MFIIV and MF low flow bypass valve closes on an actual or simulated actuation signal within the following limits: a. MBFPDV closure times 122 seconds: b. MFRV closure times 10 seconds: and. c. MFIIV closure times 120 seconds d. MFRV Low Flow Bypass valve closure time 1. primary s 10 seconds 2. backups 120 seconds. 3.7.3*3 FREQUENCY In accordance with the Inservice Testing Program Amendment 207 APR 1 O 2031

3.7 PLANT

SYSTEMS 3.7.4 Atmospheric Dump Valves (ADVs) LCO 3.7.4 Four ADV lines shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal. ACTIONS CONDITION REQUIRED ACTION A. One required ADV line A.1 Restore required ADV inoperable.

line to OPERABLE status. B. Two or more required 8.1 Restore all but one ADV lines inoperable.

ADV line to OPERABLE status. c. Required Action and C.l Be in MODE 3. associated Completion Time not met. AND C.2 Be in MODE 4 without reliance upon steam generator for heat removal. INDIAN POINT 3 3.7.4-1 ADVs 3.7.4 COMPLETION TIME 7 days 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 6 hours 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> Amendment 251 u u SURVEILLANCE REQUIREHENTS SR 3. 7.4.1 SR 3.7.4.2 INDIAN POINT 3 SURVEILLANCE Verify one complete cycle of each NJV. Verify one complete cycle of each NJV block valve. 3.7.4*2 FREQUENCY 24 months 24 months NJVs 3. 7.4 Amenanent 205

3.7 PLANT

SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Three AFW trains shall be OPERABLE.

AEW System* 3.7.5 -------------------------------NOTE----------------------

Only one AFW train, which includes a motor driven pump capable of supporting the credited steam generator(s), is required to be OPERABLE in MODE 4. APPLICABILITY:

MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal. ACTIONS -----------NOTE----------------

LCO 3.0.4.b is not applicable.

CONDITION REQUIRED ACTION A. One steam supply to A.1 Restore steam turbine driven AFW supply to OPERABLE pump inoperable.

status. B. One AFW train B.1 Restore AFW train inoperable in MODE to OPERABLE 1, 2 or 3 for status. reasons other than Condition A. INDIAN POINT 3 3.7.5-1 ., COMPLETION TIME 7 days AND --10 days from discovery of failure to meet the LCO 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND --10 days from discovery of failure to meet the LCO (continued)

Amendment 226 ACTIONS (continued)

~* CONDITION C. Required Action and associated Completion Time for Condition A or B not met. .QR Two AFW trains inoperable in HOOE 1. 2. or 3. D. Three AFW trains inoperable in HOOE 1. 2. or 3. E. Required AFW train inoperable in HOOE 4. INDIAN POINT 3 REQUIRED ACTION C.1 Be in HOOE 3. Mm C.2 Be in HOOE 4. ---------*---NOTE--**-----*----

LCO 3.0.3 and all other LCO Required Actions requiring HOOE changes are suspended until one AFW train is restored to OPERABLE status . ....*..**.......*...........**.

D.1 Initiate action to restore one AFW train to OPERABLE status. E.l Initiate action to restore AFW train to OPERABLE status. 3.7.5-2 AFW System 3.7.5 COMPLETION TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 18 hours Inrnediately Inrnediately Amenanent 205 u u AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SR 3.7.5.1 SR 3.7.5.2 SR 3.7.5.3 INDIAN POINT 3 SURVEILLANCE

---

NOTE------------*------**-

Not applicable in HOOE 4 when steam generator is relied upon for heat removal. FREQUENCY Verify each AFW manual, power operated.

and 31 days automatic valve in each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

---

*---*-*----*-*--NOTE*-**--*-***--*----*-*-

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after~ 600 psig in the steam generator.

Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head. --*--**----*-------*-NOTE*-***-**-*-****-*-****

Not applicable in HOOE 4 when steam

• generator is relied upon for heat removal. In accordance with Inservice Testing Program Verify each AFW automatic valve that is not 24 months locked. sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. (continued) 3.7.5*3 Mlenanent 205 SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.5.4 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • • • NOTES********************

1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after~ 600 psig in the steam generator.

2. Not applicable in MODE 4 when steam generator is relied upon for heat removal. Verify each AFW pump starts automatically on an actual or simulated actuation signal. 3.7.5*4 AFW System 3.7.5 FREQUENCY 24 months /IJnenanent 205 3.7 PL.ANT SYSTEMS 3.7.6 Condensate Storage Tank (CST) LCO 3.7.6 The CST shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, and 3, CST 3.7.6 HODE 4 when steam generator is rel1ed upon for heat removal. ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. CST inoperable.

A.1 Verify by aaninistrative Immediately means OPERABILITY of City Water. MID Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter MID A.2 Restore CST to OPERABLE.

7 days B. Required Action and B.1 Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. Mm B.2 Be in HOOE 4, without 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> reliance on steam generator for heat removal. INDIAN POINT 3 3.7.6*1 Amenanent 205 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.6.1 Verify the CST level is~ 360,000 gal. INDIAN POINT 3 3.7.6*2 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CST 3.7.6 Amenanent 205 u 3.7 PLANT SYSTEMS 3.7.7 City Water (CW) LCO 3.7.7 CW shall be OPERABLE.

APPLICABILITY:

HODES 1. 2. and 3. CITY WATER 3.7.7 HOOE 4 when steam generator is relied upon for heat removal. ACTIONS CONDITION REQUIRED ACTION COHPLETION TI HE A. CW inoperable.

A.l Verify by acrninistrative Invnediately means OPERABILITY of Condensate Storage Tank. MID Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> MID thereafter A.2 Restore CW to OPERABLE.

7 days B. Required Action and B.l Be in HOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. MID B.2 Be in HOOE 4. *.without 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> reliance on steam generators for heat removal. INDIAN POINT 3 3.7.7-1 /wencrnent 205 SURVEILLANCE REQUIREMENTS SR 3.7.7.1 SR 3.7.7.2 SR 3.7.7.3 INDIAN POINT 3 SURVEILLANCE Verify the CW header pressure is~ 30 psig. Verify the Unit 3 City Water Header Supply Isolation Valves are open. Perform testing required by Inservice Testing Program for each valve needed to align CW to each AFW pump suction. 3.7.7-2 CITY WATER 3.7.7 FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 31 days In accordance with the Inservice Testing Program Amendment 218

3.7 PLANT

SYSTEMS 3.7.8 Component Cooling Water (CCW) System LCO 3.7.8 Two CCW loops shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION A. One ccw loop A.1 -------NOTE-------

inoperable.

Enter applicable Conditions and Required Actions of LCO 3. 4. 6, "RCS LoopsUMODE 4, II for residual heat removal loops made inoperable by ccw. ------------------

Restore ccw loop to OPERABLE status. B. Required Action and B.1 Be in MODE 3. associated Completion Time of AND --Condition A not -----NOTE -------met. LCO 3.0.4.a is not applicable when entering MODE 4. ------------------

B.2 Be in MODE 4. INDIAN POINT 3 3.7.8-1 CCW System 3.7.8 COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Amendment 252 SURVEILLANCE REQUIREMENTS SR 3.7.8.1 SURVEILLANCE

---

NOTE-~------*-*--*--------

Isolation of CCW flow to individual components does not render the CCW System inoperable.

CCW System 3.7.8 FREQUENCY Verify each CCW manual, power operated, and 92 days SR 3.7.8.2 SR 3.7.8.3 INDIAN POINT 3 automatic valve in the flow path servicing safety related equipment, that is not locked. sealed. or otherwise secured in position, is in the correct position.

Verify each CCW automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each CCW pump starts automatically on an actual or simulated actuation signal. 3.7.8*2 24 months 24 months Amendnent 205 u 3.7 PLANT SYSTEHS 3.7.9 Service Water System (SWS) sws 3.7.9 LCO 3.7.9 Three pumps and required flow path for the essential SWS header shall be Operable:

Two pumps and required flow path for the nonessential SWS header shall be Operable.

APPLICABILITY:

HODES 1, 2, 3, and 4. -*************************************NOTE**********************************************

If LCO 3.7.9 will be met after the essential and non-essential header are swapped, then LCO 3.0.3 is not applicable for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> while swapping the essential SWS header with the nonessential SWS header. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One required SWS pump on A.1 Establish 3 OPERABLE SWS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> essential header pumps on the essential inoperable.

SWS header. B. One required SWS pump B.1 Establish 2 OPERABLE SWS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> on nonessential header pumps on the nonessential inoperable.

SWS header. (continued)

INDIAN POINT 3 3.7.9*1 Amenanent 205 ACTIONS (continued)

CONDITION C. One EOG ESFAS Service Water valve inoperable.

D. One FCU ESFAS Service Water valve inoperable.

E. SWS piping and valves inoperable for reasons other than Conditions A, B, C, or D, with no loss of safety function.

F. Required Action and associated Completion Time of Condition A, B, C, D or E not met. INDIAN POINT 3 C.1 D.l E.1 F.1 AND --F.2 REQUIRED ACTION Restore both EOG ESFAS Service Water valves to OPERABLE status. Restore both FCU ESFAS Service Water valves to OPERABLE status. Restore SWS to OPERABLE Status Be in MODE 3 -----NOTE -------LCO 3.0.4.a is not applicable when entering MODE 4. ------------------

Be in MODE 4. 3.7.9-2 sws 3.7.9 COMPLETION TIME 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Amendment 252 SURVEILLANCE REQUIREHENTS SR 3.7.9.1 SURVEILLANCE

---

*----~---------NOTE-----------*--*-------

Isolation of SWS flow to individual components does not render the SWS header inoperable.

FREQUENCY sws 3.7.9 Verify each SWS manual, power operated, and 92 days SR 3.7.9.2 SR 3.7.9.3 INDIAN POINT 3 automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify each SWS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each SWS pump starts automatically on an actual or simulated actuation signal. 3.7.9-3 24 months 24 months lvnenanent 205

3.7 PLANT

SYSTEMS 3.7.10 Ultimate Heat Sink (UHS) LCO 3.7.10 The UHS shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION A. UHS temperature>

95°F. OR UHS inoperable for reasons other than temperature>

95°F. SURVEILLANCE REQUIREMENTS A.1 AND A. 2 REQUIRED ACTION Be in MODE 3.

LCO 3.0.4.a is not applicable when entering MODE 4. Be in MODE 4. SURVEILLANCE SR 3.7.10.1 Verify average water temperature of UHS is 95°F. INDIAN POINT 3 3.7.10-1 UHS 3.7.10 COMPLETION TIME 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> 12 hours FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Amendment 252

3.7 PLANT

SYSTEMS 3.7.11 Control Room Ventilation System (CRVS) LCO 3.7.11 Two CRVS trains shall be OPERABLE.

-NOTE -CRVS 3.7.11 The control room envelope (CRE) boundary may be opened intermittently under administrative control. APPLICABILITY:

MODES 1, 2, 3 and 4, During movement of recently irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRVS train inoperable A.1 Restore CRVS train to 7 days for reasons other than OPERABLE status. Condition B. B. One or more CRVS trains B.1 Initiate action to implement Immediately inoperable due to mitigating actions. inoperable CRE boundary in MODE 1, 2, 3, or 4. Al'JD B.2 Verify mitigating actions ensure CRE occupant exposures to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> radiological, chemical, and smoke hazards will not exceed limits. AND B.3 Restore CRE boundary to OPERABLE status. 90 days C. Two CRVS trains inoperable C.1 Restore one CRVS train to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> for reasons other than OPERABLE status. Condition B INDIAN POINT 3 3.7.11-1 Amendment 239 ACTIONS (continued)

D. Required Action and associated Completion Time of Condition A, B or C not met in Mode 1, 2, 3, or 4. D. 1 Be in MODE 3 . AND LCO 3.0.4.a is not applicable when entering MODE 4. D.2 Be in MODE 4. CRVS 3. 7 .11 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours E. One CRVS train inoperable E.1 Place OPERABLE CRVS train Irrmediately during movement of recently in pressurization mode. irradiated fuel assemblies.

OR E.2 Suspend movement of recently irradiated fuel assemblies.

F. Two CRVS trains inoperable during movement of recently irradiated fuel assemblies.

F.1 Suspend movement of recently irradiated fuel assemblies.

OR One or more CRVS trains inoperable due to an inoperable CRE boundary during movement of recently irradiated fuel assemblies.

SURVEILLANCE REQUIREMENTS SR 3.7.11.1 SR 3.7.11.2 SR 3. 7 .11.3 SURVEILLANCE Operate each CRVS train for~ 15 minutes. Perform required CRVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP) . Verify each CRVS train actuates on an actual or simulated actuation signal. SR 3.7.11.4 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program. INDIAN POINT 3 3.7.11-2 Irrmediately Irrmediately FREQUENCY 31 days In accordance with VFTP 24 months In accordance with the Control Room Envelope Habitability Program Amendment 252

3.7 PLANT

SYSTEMS 3.7.12 Control Room Air Conditioning System (CRACS) LCO 3.7.12 Two CRACS trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3 and 4, ACTIONS CONDITION REQUIRED ACTION A. One CRACS train A.1 Restore CRACS inoperable.

train to OPERABLE status. B. Two CRACS trains B.1 Restore one CRACS inoperable.

train to OPERABLE status. C. Required Action and C.1 Be in MODE 3. associated Completion Time of AND --Condition A or B -----NOTE -------not met. LCO 3.0.4.a is not applicable when entering MODE 4. ------------------

C.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.12.1 Verify each CRACS train has the capability to remove the assumed heat load. INDIAN POINT 3 3.7.12-1 CRACS 3.7.12 COMPLETION TIME 30 days 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> FREQUENCY 24 months Amendment 252 u u 3. 7 PLANT SYSTEMS 3. 7 .13 Fuel Storage Building Emergency Ventilation System (FSBEVS) LCO 3.7.13 FSBEVS shall be OPERABLE.

FSBEVS 3.7.13 APPLICABILITY:

During movement of recently irradiated fuel assemblies in the fuel storage building.

ACTIONS CONDITION A. FSBEVS inoperable.

A.1 INDIAN POINT 3 REQUIRED ACTION Suspend movement of recently irradiated fuel assemblies in the fuel storage building.

3.7.13-1 COMPLETION TIME Immediately Amendment 215

• MAR 17 2003 SURVEILLANCE REQUIREMENTS SR 3.7.13.1 SR 3.7.13.2 SR 3.7.13.3 SR 3. 7 .13.4 SR 3.7.13.5 INDIAN POINT 3 SURVEILLANCE Verify FSBEVS charcoal filter bypass dampers are installed.

Operate FSBEVS for~ 15 minutes. Perform required FSBEVS filter testing in accordance with the Ventilation Filter Testing Program CVFTP). Verify FSBEVS actuates on an actual or simulated actuation signal. Verify FSBEVS can maintain a pressure -0.125 inches water gauge with respect to atmospheric pressure during the post accident mode of-operation at a flow rate~ 20,000 cfm. 3.7.13*2 FSBEVS 3.7.13 FREQUENCY 92 days 31 days In accordance with the VFTP 92 days 24 months Amenctnent 205

3.7 PLANT

SYSTEHS Spent Fuel Pit Water Level 3.7.14 3.7.14 Spent Fuel Pit Water Level LCO 3.7.14 APPLICABILITY:

ACTIONS The spent fuel pit water level shall be~ 23 ft over the top of irradiated fuel assemblies seated in the storage racks. During movement of irradiated fuel assemblies in the spent fuel pit. CONDITION REQUIRED ACTION COMPLETION TIHE A. Spent fuel pit water level not within limit. A.l *********NOTE**********

LCO 3.0.3 is not applicable.

Suspend movement of

• Inrnediately irradiated fuel assemblies in the spent fuel pit. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the spent fuel pit water level is~ 23 ft 7 days above the top of the irradiated fuel assemblies seated in the storage racks. INDIAN POINT 3 3.7.14*1 Arnenctnent 205

3.7 PLANT

SYSTEMS

• Spent Fuel Pit Boron Concentration 3.7.15 3. 7 .15 Spent Fuel Pit Boron Concentration LCD 3.7.15 APPLICABILITY:

ACTIONS The Spent Fuel Pit boron concentration shall be~ 1000 ppm. ---------------------------NOTE-------------------------

During inter-unit transfer of fuel the spent fuel pit boron concentration must also meet Appendix C LCD 3.1.1, "Boron Concentration".

When fuel assemblies are stored in the spent fuel pit and a spent fuel pit verification has not been perfonned since the last movement of fuel assemblies in the spent fuel pit. CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pit boron concentration not within l i mi t. INDIAN POINT 3 A.1 -----------NOTE----------

LCO 3.0.3 is not applicable.

Suspend movement of fuel assemblies in the spent fuel pit. A.2.1 Initiate action to restore spent fuel pit boron concentration to within limit. A.2.2 Initiate action to perfonn a spent fuel pit verification.

3.7.15-1 Immediately Immediately Immediately l\mendment 246

\ . '\..__../

I , Spent Fuel Pit Boron Concentration 3.7.15 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the spent fuel pit boron concentration is 31 days within limit. INDIAN POINT 3 3.7.15-2 Amenanent 205 u 3.7 PLANT SYSTEHS Spent Fuel Assembly Storage 3.7.16 3.7.16 Spent Fuel Assembly Storage LCO 3.7.16 APPLICABILITY:

INDIAN POIITT 3 Fuel assemblies stored in the spent fuel pit shall be classified in accordance with Figure 3.7.16*1 based on initial enrichment and burnup; and, Fuel assembly storage location within the spent fuel pit shall be restricted based on the Figure 3.7.16*1 classification as follows: a. Fuel assemblies classified as Type 2 may be stored in any location in either Region 1 or Region 2; b. Fuel assemblies classified as Type IA. 18 or IC shall be stored in Region 1; c. Fuel assembly storage location within Region 1 shall be restricted as follows: 1. Type 1A assemblies may be stored anywhere in Region 1; 2. Type 18 assemblies may be stored anywhere in Region 1. except a Type 18 assembly shall not be stored face-adjacent to a Type IC assembly;

3. Type IC assemblies shall not be stored in Row 64 or in Column ZZ; and 4. Type IC assemblies shall be stored in Region 1 locations

• where all face-adjacent locations are as follows: a) occupied by Type 2 or Type lA assemblies, or b) occupied by non-fuel components.

or c) empty. Whenever any fuel assembly is stored in the spent fuel pit. 3.7.16*1 Pmenonent 205 I ' \..J Spent Fuel Assembly Storage 3.7.16 ACTIONS CONDITION A. Requirements of the LCO not met. A.l REQUIRED ACTION ---------NOTE----------

LCO 3.0.3 is not applicable.

COHPLETION TIHE Initiate action to move Immediately fuel to restore compliance with LCO 3.7.16. SURVEILLANCE REQUIREHENTS SR 3.7.16.1 INDIAN POINT 3 SURVEILLANCE Verify by aaninistrative means the initial enrichment and burnup of each fuel assembly and that the storage location meets LCO 3.7.16 requirements.

3.7.16*2 FREQUENCY Prior to storing the fuel assembly in the spent fuel pit Amenanent 205 40000 I 35000 I 30000 25000 I ' -:, I-:E -C ;: 20000 ::5. Q. :, E :, m 15000 10000 , V ' I 5000 I I ' I I/ . 0 I 1.5 2.0 ~! INDIAN POINT 3 I ' I I ' I ' I I I ' / i/ --,. ....... I I " I ' I ,,. / / / i/ / ' / / *,v LIi -.. / ' -. 7 ' / / / " I I ' , I I I . I I -* .. ;-. I ' a I .. . -~ I I ... ii --2.5 3.0 3.5 Spent Fuel Assembly Storage 3.7.16 I -1 I I ' ' ' 1 V . I . . / ' -, ,., ' ' I 7 -,, ' '/ ---, I/ I -u / I 17 I I ,I / I I ' ' ' ' I n . ' . I --, I 'II JI I .. .. .. *--I I c;c -~ ... '""---. -i, -u. ") I ' ..,-1 4.0 4.5 5.0 :Initia1 U-235 Enrichment (w/o) Figure 3.7.16-1 (Page 1 of 1) Fuel Assembly Classification for Storage in the Spent Fuel Pit 3.7.16*3 Amenonent 205

3.7 PLANT

SYSTEMS 3.7.17 Secondary Specific Activity Secondary Specific Activity 3.7.17 LCO 3.7.17 The specific activity of the secondary coolant shall be~ 0.10 µCi/gn DOSE EQUIVALENT 1*131. APPLICABILITY:

HODES 1, 2, 3, and 4. ACTIONS CONDITION A. Specific activity not within limit. SURVEILLANCE REQUIREMENTS A.l A.2 SURVEILLANCE REQUIRED ACTION Be in HOOE 3. Be in HODE s.* SR 3.7.17.1 Verify the specific activity of the secondary coolant is~ 0.10 µCi/gn DOSE EQUIVALENT I-131. INDIAN POINT 3 3.7.17*1 COMPLETION TIHE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours FREQUENCY 31 days AmenO'llent 205 u u \_J 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 sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Electrical Power Distribution System; and b. Three diesel generators (DGs) (31, 32 and 33) capable of supplying the onsite power distribution subsystem(s)

---

Note------------------------

The 138 kV circuit is considered inoperable whenever the automatic transfer function for,the 6.9 kV buses is disabled.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS ------------------------------------Note-------------------------------

The LCO 3.0.4.b is not applicable to DGs or the 138kV offsite circuit. CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite A.1 Perform SR 3.8.1.1 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> circuit for OPERABLE offsite inoperable.

circuit. AND AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter (continued)

,,,, INDIAN POINT 3 3.8.1 -1 Amendment 226 .,

ACTIONS CONDITION A. (continued)

V INDIAN POINT 3 REQUIRED ACTION *********NOTE***********

Only required if 13.8 kV offsite circuit is supplying 6.9 kV bus 5 or 6 and the Unit Auxiliary Transformer is supplying 6.9 kV bus 1, 2, 3 or 4. AC Sources -Operating

3.8.1 COMPLETION

TIHE A.2 Verify automatic transfer 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of 6.9 kV buses 1, 2, 3, A.3 A.4 and 4 to 6.9 kV bus 5 and ANO . 6 is disabled.

Declare inoperable required feature(s) with no offsite power automatically available when its redundant required feature(s) is inoperable.

• Restore offsite circuit to OPERABLE status. 3.8.1-2 Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from discovery of no automatically available offsite power to one train concurrent . with inoperability of redundant required feature(s) 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (continued)

Amenonent 205 ACTIONS (continued)

CONDITION B. One DG inoperable.

~I INDIAN POINT 3 REQUIRED ACTION AC Sources -Operating

3.8.1 COMPLETION

TIHE. B.1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> offsite circuits.

B.2 Declare inoperable the required features supported by the inoperable DG when its required redundant feature is inoperable.

MID B.3.1 Determine OPERABLE DG(s) are not inoperable due to c011111on cause failure. OR B.3.2 Perform SR 3.8.1.2 for OPERABLE DGs. MID B.4 Restore DG to OPERABLE status. 3.8.1-3 Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoperability of redundant required feature 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (continued)

Arnendnent 205 ACTIONS {continued)

CONDITION C. Two offsite circuits C.1 inoperable.

M:!Q C.2 0. One offsite circuit inoperable.

M:!Q One 0G inoperable.

0.1 QR 0.2 INDIAN POINT 3 REQUIRED ACTION Declare required features inoperable when its redundant required feature is inoperable.

Restore one offsite circuit to OPERABLE status. ***********NOTE**********

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems-Operating," when Condition Dis entered* with no offsite or 0G AC power source automatically available to any train . ..*..**...**...*...*.....

Restore offsite circuit to OPERABLE status. Restore 0G to OPERABLE status. 3.8.1-4 AC Sources -Operating

3.8.1 COMPLETION

TIHE 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from discovery of Condition C concurrent with inoperability of redundant required feature 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 12 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> {continued)

Amenanent 205 ACTIONS (continued)

CONDITION E. Two or more DGs inoperable.

F. Required Action and associated Completion Time of Condition A, B, C, D, or E not met. G. One or more offsite circuits and two DGs inoperable.

H. Two offsite circuits and one or more DGs inoperable.

INDIAN POINT 3 REQUIRED ACTION E.l Restore at least DGs to OPERABLE status. F.l Be in MODE 3. AND -----NOTE ----LCO 3.0.4.a is applicable when AC Sources -Operating

3.8.1 COMPLETION

TIME two 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 6 hours not entering MODE 4. -------------

F.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> G.l Enter LCO 3.0.3. Immediately H.l Enter LCO 3.0.3. Immediately 3.8.1 -5 Amendment 252 AC Sources -Operating

3.8.1 SURVEILLANCE

REQUIREHENTS SR 3.8.1.1 SR 3.8.1.2 SR 3.8.1.3 INDIAN POINT 3 SURVEILLANCE Verify correct breaker alignment and indicated power availability for each offsite circuit. *********************NOTE***********************

All DG starts may be preceded by an engine prelube period. FREQUENCY 7 days Verify each DG starts from standby conditions and 31 days achieves:

a. in~ 10 seconds, voltage~ 422 V and frequency~

58.8 Hz: and b. steady state voltage~ 422 V and~ 500V, and frequency~

58.8 Hz and~ 61.2 Hz. *********************NOTES*********************

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test. 3. This SR shall be conducted on only one DG at a time. 4. This SR sha 11 be preceded by and irrmediately follow without shutdown a successful performance of SR 3.8.1.2. Verify each DG is synchronized and loaded and 31 days operates for~ 60 minutes at a load~ 1575 kW and 1750 kW. . (continued) 3.8.1-6 Amendment 205 AC Sources Operating

3.8.1 SURVEILLANCE

REQUIREMENTS (continued)

SR 3.8.1.4 SR 3.8.1.5 SR 3.8.1.6 SR 3.8.1.7 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify each day tank contains~

115 gal of fuel 31 days oi 1. Check for and remove accumulated water from 31 days each day tank. Verify the fuel oil transfer system operates to 31 days automatically transfer fuel oil from DG storage tank to the day tank. --------------------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.

Verify manual transfer of AC power sources from 24 months the normal offsite circuit to the alternate offsite circuit. 3.8.1 -7 Amendment 242 AC Sources Operating

3.8.1 SURVEILLANCE

REQUIREMENTS (continued)

SR 3.8.1.8 SR 3.8.1.9 INDIAN POINT 3 SURVEILLANCE

---

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

1. This Surveillance shall not normally be performed in MODE 1 or 2. However this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

2. Only required to be met if 138 kV offsite circuit is supplying 6.9 kV bus 5 and 6 and the Unit Auxiliary Transformer is supplying 6.9 kV bus 2 or 3. Verify automatic transfer of AC power for 6.9 kV buses 2 and 3 from the unit auxiliary transformer to 6.9 kV buses 5 and 6. --------------------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.

Verify each DG 1 s automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except: a. Engine overspeed;

b. Low lube oil pressure; and c. Overcrank relay. 3.8.1 -8 FREQUENCY 24 months 24 months Amendment 242 AC Sources -Operating

3.8.1 SURVEILLANCE

REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.1.10 -----------------------NOTES-------------------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test. 2. This Surveillance shall not normally be performed in MODE 1 or 2. However this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

3. If performed with DG synchronized with offsite power, it shall be performed at a power factor of 0.85 for EOG 31, 0.87 for EOG 32, and~ 0.84 for EOG 33. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

4. Prior to performing SR 3.8.1.10 while connected to the 13.8 kV offsite power, the grid condition must be evaluated to show that conditions exist to reasonably allow the required power factor limits to be met or perform the SR while connected to the 138 kV offsite power. Verify each DG operates for~ 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />s: a. For 105 minutes loaded 1925kW and 1941 kW; and b. For the remaining hours of the test loaded 1700kW and~ 1750 kW. SR 3.8.1.11 ----------------------NOTE----------------------------

Load timers associated with equipment that has automatic initiation capability disabled are not required to be operable.

Verify each time delay relay functions within the required design interval.

FREQUENCY 24 months 18 months (continued)

INDIAN POINT 3 3.8.1 -9 Amendment 242 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.12 INDIAN POINT 3 ---------------------NOTES---------------------

1. All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1. 2. 3 0 or 4. However portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

3. This SR may be performed on safeguards power trains one at a time, or simultaneously.

Appropriate plant conditions must be established when testing three safeguards power trains simultaneously.

Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: a. De-energization of emergency buses; b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads ins 10 seconds. 2. energizes auto-connected emergency loads through individual load timers, 3. achieves steady state voltage~ 422 V ands 500 V, 4. achieves steady state frequency 58.8 Hz ands 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for 5 minutes. 3.8.1 -10 AC Sources -Operating 3.8.1 24 months (continued)

Amendment 242 AC Sources Operating

3.8.1 SURVEILLANCE

REQUIREMENTS (continued)

SR 3.8.1.13 INDIAN POINT 3 SURVEILLANCE

---

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

1. All DG starts may be preceded by an engine prelube period. 2. Performance of SR 3.8.1.12 may be used to satisfy the requirements of this SR if all three diesel generators are started simultaneous 1 y. FREQUENCY Verify when started simultaneously from standby 10 years condition, each DG achieves:

a. in~ 10 seconds, voltage~ 422 V and frequency~

58.8 Hz; and b. steady state voltage~ 422 V and~ 500V, and frequency~

58.8 Hz and~ 61.2 Hz. 3.8.1-11 Amendment 242 V ~/ AC Sources -Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEHS 3 8. 2 AC Sources -Shutdown LCO 3.8.2 APPLICABILITY:

ACTIONS The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the*offsite transmission network and the onsite AC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems-Shutdown":

and b.1 Two diesel generators CDGs) capable of supplying two safeguards power trains of the onsite AC electrical power distribution subsystem(s) required by LCO 3.8.10: or b.2. One DG capable of supplying necessary portions of the onsite AC electrical power distribution subsytems required by LCO 3.8.10 provided that: Ca) The reactor has been subcritical for at least 5 days.and Cb) The water level in the refueling cavity is~ 23 feet above the reactor vessel flange, or there is no fuel in the reactor vessel and the refueling cavity. HODES 5 *and 6, During movement of irradiated fuel assemblies.

CONDITION REQUIRED ACTION COMPLETION TIHE A. One required offsite circuit inoperable.

INDIAN POINT 3 . ---* ----* ----NOTE* * * * * * * * * * * * * *

• Enter applicable Conditions and Required Actions of LCO 3.8.10, with any required bus de-energized as a result of Condition A. 3.8.2-1 (continued)

/wendnent 205

~I ACTIONS CONDITION A.1 (contil')ued)

A.1 QR A.2.1 M:iQ A.2.2 M:iQ V A.2.3 M:iQ A.2.4 INDIAN POINT 3 REQUIRED ACTION Declare affected required feature(s) with no offsite power available inoperable.

Suspend CORE ALTERATIONS.

Suspend movement of irradiated fuel assemblies.

Initiate action to suspend operations involving positive reactivity additions.

Initiate action to restore required offsite power circuit to OPERABLE status. 3.8.2-2 AC Sources -Shutdown 3.8.2 COMPLETION TIME I11111ediately I11111ediately I11111ediately I11111ediately I11111ediately (continued)

Amencknent 205 ACTIONS -CONDITION B. Required DG(s) inoperable B.1 B.2 *B.3 \.J B.4 u INDIAN POINT 3 MID MID, REQUIRED ACTION Suspend CORE ALTERATIONS.

Suspend movement of irradiated fuel assemblies.

Initiate action to suspend operations involving positive reactivity additions.

Initiate action to restore required DGCs) to OPERABLE status. 3.8.2-3 AC Sources -Shutdown 3.8.2 COHPLETION TI HE Invnediately Invnediately Invnediately Invnediately Arnenanent 205 V SURVEILLANCE REQUIREMENTS SR 3.8.2.1 INDIAN POINT 3 SURVEILLANCE

-*-------------*----NOTES-----------------------

1. The following SRs are required to be met but are not required to be performed:

SR 3.8.1.3. SR 3.8.1.10.

SR 3.8.1.11.

and SR 3.8.1.12.

2. Portions of SR 3.8.1.12 regarding an actual or simulated ESF actuation signal are not required to be met.

• For AC sources required to be OPERABLE.

the SRs of Specification 3.8.1. "AC Sources-Operating." except SR 3.8.1.8, SR 3.8.1.9. and SR 3.8.1.13.

are applicable.

3.8.2-4 AC Sources -Shutdown 3.8.2 FREQUENCY In accordance with applicable SRs Amenanent 205

3.8 ELECTRICAL

POWER SYSTEMS 3.8.3 Diesel Fuel Oil and Starting Air Diesel Fuel Oil and Starting Air 3.8.3 LCO 3.8.3 The stored diesel fuel oil and starting air subsystem shall be within limits for each required diesel generator (DG). APPLICABILITY:

When associated DG is required to be OPERABLE.

ACTIONS ---------*------------------------------NOTE---------------------*----------------------

Separate Condition entry is allowed for each DG. CONDITION REQUIRED ACTION COMPLETION TI HE A. ----------NOTE----------

A.1 Declare associated DG Immediately Only applicable in inoperable.

HODES 1, 2, 3 and 4 . ........*.....*.........

One or more DGs with usable fuel oil in associated DG fuel oil storage tank< 5365 gal. B. ----------NOTE----------

8.1 Deel are all DGs Immediately Only applicable in inoperable.

HODES 5 and 6 and during movement of irradiated fuel * ......................*.

Total combined usable fuel oil in DG fuel oil storage tanks associated with the operable DGCs) < 5365 gal. (continued)

INDIAN POINT 3 3.8.3-1 Amendnent 205 ACTIONS (continued)

CONDITION C. * ********NOTE*********.**

C.1 Only applicable in HODES 1, 2, 3 and 4 * ....*.......**..........

Total useable fuel oil in reserve storage tank(s) < 26,826 gal. D. One or more 0G fuel oil D.1 storage tanks or reserve fuel oil storage tanks with fuel oil total particulates not within limits. E. One or more DG fuel oil E.1 storage tanks or reserve fuel oil storage tanks with fuel oil properties other than particulates not within limits. F. One or more DGs with F.1 starting air receiver pressure<

250 psig and*~ 90 psig. INDIAN POINT 3 Diesel Fuel Oil and Starting Air 3.8.3 REQUIRED ACTION COMPLETION TI HE Deel are all DGs I11111ediately inoperable.

Restore fuel oil total 7 days for DG fuel particulates within oil storage tank limit. Mm 30 days for reserve fuel oil storage tank Restore fuel oil 30 days for DG properties to within fuel oil storage limits. tank Mm 60 days for reserve fuel oil storage tank Restore starting air 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> receiver pressure to 250 psig. (continued) 3.8.3*2 Amencinent 205 ACTIONS (continued)

CONDITION G. Required Action and associated Completion Time not met. One or more DGs diesel fuel oil or starting air subsystem not within limits for reasons other than Condition A, 8, C, D, E, or F. INDIAN POINT 3 G.1 Diesel Fuel Oil and Starting Air 3.8.3 REQUIRED ACTION Declare associated 0G inoperable.

3.8.3-3 COHPLETION TI HE Invnediately ,dmendnent 205 u u Diesel Fuel Oil and Starting Air 3.8.3 SURVEILU\NCE REQUIREMENTS SR 3.8.3.1 SR 3.8.3.2 SR 3.8.3.3 INDIAN POINT 3 SURVEILU\NCE

• • • • • • • • • • • • • • • • • • • • • NOTE**********************

Only required in HODES 1, 2, 3 and 4. Verify reserve storage tank(s) contain 26,826 gal of fuel oil reserved for IP3 usage only. Verify DG fuel oil storage tanks contain: a. Usable fuel oil volume~ 5365 gal in each storage tank when in HODES 1, 2, 3 and 4: and b. Total combined usable fuel oil volume 5365 gal in any DG fuel oil storage tank(s) that are associated with the operable DG(s) when in HODES 5 and 6 and during movement of irradiated fuel assemblies.

Verify that fuel oil properties of new and stored fuel oil in the DG fuel oil storage tanks are tested and maintained in accordance with the Diesel Fuel Oil Testing Program. 3.8.3*4 FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 31 days In accordance with the Diesel Fuel Oil Testing Program (continued)

Amenanent 205 u u Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREHENTS (continued)

SR 3.8.3.4 SR 3.8.3.5 SR 3.8.3.6 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • • NOTE**********************

Only required in HODES 1, 2, 3 and 4. Verify that fuel oil properties in the reserve storage tankCs) are within limits specified in the Diesel Fuel Oil Testing Program. FREQUENCY In accordance with the Diesel Fuel Oil Testing Program Verify each DG air start receiver pressure is 31 days 250 psig. Check for and remove accumulated water from each 92 days DG fuel oil storage tank. 3.8.3*5 Amenanent 205 DC Sources -Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources -Operating LCO 3.8.4 The following four DC electrical power subsystems shall be OPERABLE:

Battery 31 and associated Battery Charger; Battery 32 and associated Battery Charger; Battery 33 and associated Battery Charger; and Battery 34. APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION A. DC electrical power A.1 Declare Inverter 34 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> subsystem 34 inoperable and take Inoperable.

Required Actions specified in LCO 3. 8. 7, Inverters-Operating.

B. One DC electrical B.l Restore DC 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> power subsystem (31 electrical power or 32 or 33) subsystem to inoperable.

OPERABLE status. C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Associated Completion Time not AND --met. ---NOTE ----LCO 3.0.4.a is not applicable when entering MODE 4. -------------

C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> TIME INDIAN POINT 3 3.8.4-1 Amendment 252 DC Sources -Operating

3.8.4 SURVEILLANCE

REQUIREMENTS SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify battery terminal voltage on float charge 31 days is within the following limits: a. 125.7 V for battery 31; b. 123.5 V for battery 32; and c. 127.8 V for batteries 33 and 34. ---------------------NOTE----------------------

This Surveillance shall not normally be performed in MODE l, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each battery charger supplies its associated battery at the voltage and current adequate to demonstrate battery charger capability requirements are met. ---------------------NOTES---------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. 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 or a modified performance discharge test. 3.8.4 -2 24 months 24 months (continued)

Amendment 242 u u DC Sources -Operating

3.8.4 SURVEILLANCE

REQUIREMENTS (continued)

SR 3.8.4.4 SR 3.8.~.5 INDIAN POINT 3 SURVEILLANCE

---

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

This Surveillance shall not be perfonned in MODE 1, 2, 3, or 4. Verify battery capacity is~ 80% of the manufacturer's rating when subjected to a perfonnance discharge test or a modified perfonnance discharge test. FREQUENCY 60 months 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 expected life with capacity 100% of manufacturer's rating Verify battery cells, cell plates, and racks 24 months show no visual indication of physical damage or abnonnal deterioration.

3.8.4 -3 Amendment

-~ 16 MAR 2 5 2003 , .. .,.

\.__,,,J 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown DC Sources -Shutdown 3.8.5 LCO 3.8.5 DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystems required by LCO 3.8.10, "Di stri buti on Systems -Shutdown." APPLICABILITY:

HODES 5 and 6, During movement.of irradiated fuel assemblies.

ACTIONS CONDITION

• REQUIRED ACTION COMPLETION TIME A. One or more required DC A.1 Declare affected I11111ediately electrical power required feature(s) subsystems inoperable.

inoperable.

QR A.2.1 Suspend CORE I11111ediately ALTERATIONS.

Mm A.2.2 Suspend movement of I11111ediately i rr adi ated f ue 1 assemblies.

-Mm A.2.3 Initiate action to I11111ediately suspend operations involving positive reactivity additions.

Mm (continued)

INDIAN POINT 3 3.8.5-1 Amendment 205 ACTIONS CONDITION REQUIRED ACTION A. (continued)

A.2.4 Initiate action to restore required DC electrical power subsystems to OPERABLE status. SURVEILLANCE REQUIREMENTS SR 3.8.5.1 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • • • • NOTE**********************

The following SRs are not required to be performed:

SR 3.8.4.2. SR 3.8.4.3. and SR 3.8.4.4. For DC sources required to be OPERABLE.

the following SRs are applicable:

SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 SR 3.8.4.4. 3.8.5*2 DC Sources -Shutdown 3.8.5 COMPLETION TIME Invnediately FREQUENCY In accordance with applicable SRs Amendnent 205

3.8 ELECTRICAL

POWER SYSTEMS 3.8.6 Battery Cell Parameters Battery Cell Parameters 3.8.6 LCO 3.8.6 Battery cell parameters for batteries 31, 32, 33 and 34 shall be within the limits of Table 3.8.6*1. APPL! CAB I LITY: 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 Verify pilot cells 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> with one or more battery electrolyte level and cell parameters not float voltage meet within Category A or B Table 3.8.6-1 Category C limits. limits. AHO A.2 Verify battery cell 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> parameters meet Table 3.8.6-1 Category C AHO limits. Once per 7 days thereafter A.3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6* l. C continued)

INDIAN POINT 3 3.8.6*1 Amenanent 205 ACTIONS (continued)

CONDITION B. Required Action and associated Completion Time of Condition A not met. One or more batteries with average electrolyte temperature of the representative cells not within limits of SR 3.8.6.3. One or more batteries with one or more battery cell parameters not within Category C values. INDIAN POINT 3 B.1 REQUIRED ACTION Declare associated battery inoperable.

3.8.6-2 Battery Cell Parameters

3.8.6 COMPLETION

TIHE Inrnediately Amencinent 205 Battery Cell Parameters

3.8.6 SURVEILLANCE

REQUIREMENTS SR 3.8.6.1 SR 3.8.6.2 SR 3.8.6.3 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify battery cell parameters meet Table 3.8.6-1 31 days Category A limits. Verify battery cell parameters meet Table 3.8.6*1 92 days Category B limits. Verify average electrolyte ternp*erature of 92 days representative cells is within the following limits: a. 60°F for batteries 31, 32 and 34; and b. 35°F for battery 33. 3.8.6*3 Amenonent 205

. PARAMETER Electrolyte Level ' Float Voltage Specific GravityCb)(c)

Table 3.8.6-1 (page 1 of 1) Battery Cell Parameters Requirements CATEGORY A: LI HITS FOR EACH CATEGORY B: DESIGNATED PILOT LIMITS FOR EACH CELL CONNECTED CELL > Hinimtnn level > Hinimtnn level indication mark, indication mark, and-~~ inch above and~~ inch above maximtnn level maximum level indication markCa) indication markCa) 2.13 V 2.13 V 1.205 1.195 AHO Average of all connected cells > 1.205 Battery Cell Parameters

3.8.6 CATEGORY

C: ALLOWABLE LIMITS FOR EACH CONNECTED CELL Above top of plates, and not over fl ow1 ng > 2.07 V Not more than 0.020 below average of all connected cells AHO Average of all connected cells 1.195 Ca) It is acceptable for the electrolyte level to temporarily increase above the specified maximum during.equalizing charges provided it is not overflowing.

Cb) Corrected for electrolyte temperature.

Cc) A battery charging current of <2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific*gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

INDIAN POINT 3 3.8.6*4 Amenanent 205 Inverters

-Operating 3_8.7 3.8 ELECTRICAL POWER SYSTEMS V 3.8. 7 Inverters -Operating u LCO 3.8.7 Inverters

31. 32, 33 and 34 shall be OPERABLE:

and Two constant voltage transformers CCVTs) capable of supplying 120 V AC vital instrument bus (VIB} 34 shall be OPERABLE.

APPLICABILITY:

HODES 1, 2, 3, and 4. ACTIONS -------------------------------------------

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

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems -Operating" with any required bus de-energized.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required CVT A.l Restore CVT to OPERABLE 30 days inoperable.

status. B. Two required CVTs B.1 Restore one CVT to 7 days inoperable.

OPERABLE status. (continued)

INDIAN POINT 3 3.8.7-1 Amencinent 205 ACTIONS (continued)

CONDITION C. One inverter inoperable.

D. Required Action and associated Completion Time not met. C.1 AND Inverters

-Operating

3.8.7 REQUIRED

ACTION Only applicable to feature(s) that require power to perform the required safety function.

Declare required feature(s) supported by associated inverter inoperable when the required redundant feature(s) is inoperable.

COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> from discovery of Condition C concurrent with inoperability of redundant required feature(s)

C. 2 Restore inverter to 7 days D.l AND OPERABLE status. Be in MODE 3. -----NOTE --LCO 3.0.4.a is not applicable when entering MODE 4. D.2 Be in MODE 4. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours INDIAN POINT 3 3.8.7-2 Amendment 252 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.7.1 Verify correct inverter voltage, frequency, and alignment to required 120V AC vital instrument buses. SR 3.8.7.2 Verify manual transfer of the AC power source for VIB 34 from inverter 34 to each required CVT. INDIAN POINT 3 3.8.7 -3 Inverters

-Operating 3.8.7* FREQUENCY 7 days 24 months Amendment 234 V \_/' 3.8 ELECTRICAL POWER SYSTEHS 3.8.8 Inverters -Shutdown Inverters

-Shutdown 3.8.8 LCD 3.8.8 Inverters shall be OPERABLE to support the onsite 120 V AC vital instrument bus CVIB) electrical power distribution subsystems re qui red by LCD 3. 8 .10. "Di stri buti on Systems -Shutdown." APPLICABILITY:

HODES 5 and 6. During movement of irradiated fuel assemblies.

ACTIONS CONDITION A. One or more required inverters inoperable.

INDIAN POINT 3 A.l QR A.2.1 A.2.2 A.2.3 REQUIRED ACTION Declare affected required feature(s) inoperable.

Suspend CORE ALTERATIONS.

Suspend movement of irradiated fuel assemblies.

Initiate action to suspend operations involving positive reactivity additions.

3.8.8*1 COMPLETION TIHE Immediately Immediately Immediately Immediately (continued)

/iJnenanent 205 u ACTIONS (continued)

CONDITION REQUIRED ACTION A. (continued)

A.2.4 Initiate action to restore required inverters to OPERABLE status. SURVEILLANCE REQUIREMENTS SR 3.8.8.1 INDIAN POINT 3 SURVEILLANCE

• • • • • • • • • • • • • • • • • • NOTE******************

Frequency verification not required to be performed for inverter 34. Verify correct inverter voltage. frequency.

and alignments to required 120 V AC vital instrument buses. 3.8.8*2 Inverters

-Shutdown 3.8.8 COMPLETION TIME Irrmediately FREQUENCY 7 days Amendnent 205

\__,,,1 t J 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems-Operating Di stri buti on Systems -Operating 3.8.9 LCO 3.8.9 AC. DC. and 120 V AC vital instrument bus VIB electrical power distribution subsystems for safeguards power trains 5A, 6A and 2A/3A shall be OPERABLE.

APPLICABILITY:

HODES 1, 2. 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One AC electrical power A.I Restore AC electrical 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> distribution subsystem power distribution inoperable With no loss* subsystem to OPERABLE Mm of safety function.

status. 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO B. One VIB inoperable with B.1 Restore VIB to OPERABLE 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> no loss of safety status. function.

Mm 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO (continued)

INDIAN POINT 3 3.8.9*1 .Amenanent 205 Distribution Systems -Operating

3.8.9 ACTIONS

(continued)

CONDITION C. One DC electrical power distribution subsystem inoperable with no loss of safety function.

C.1 REQUIRED ACTION Restore DC electrical power distribution subsystem to OPERABLE status. COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO D. Required Action and associated Completion Time not met. D.1 AND Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> D.2 E. One or more trains E.1 with inoperable distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS LCO 3.0.4.a is not applicable when entering MODE 4. Be in MODE 4. Enter LCO 3.0.3. SURVEILLANCE SR 3.8.9.1 Verify correct breaker alignments and voltage to required AC, DC, and VIB electrical power distribution subsystems.

INDIAN POINT 3 3.8.9 -2 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Immediately FREQUENCY 7 days Amendment 252

\.__J u 3.8 ELECTRICAL POWER SYSTEMS 3. 8 .10 Di stri buti on Systems -Shutdown Di stri buti on Systems -Shutdown 3.8.10 LCO 3.8.10 The necessary portion of AC, DC, and 120 V AC vital instrument bus CVIB) electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

• APPLICABILITY:

HODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. One or more required AC, A.1 Declare associated Immediately DC, or AC vital supported required instrument bus electrical feature(s) inoperable.

power distribution subsystems inoperable.

08 A.2.1 Suspend CORE Immediately ALTERATIONS.

MfQ A.2.2 Suspend movement of Invnediately irradiated fuel assemblies.

MfQ A.2.3 Initiate action to Immediately suspend operations involving positive reactivity additions. (continued)

INDIAN POINT 3 3.8.10*1 Amendment 205 ACTIONS Di stri buti on Systems -Shutdown 3.8.10 CONDITION REQUIRED ACTION COHPLETION TIHE A. (continued)

A.2.4 Initiate actions to I11111ediately A.2.5 restore required AC. DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status. Declare associated required residual heat removal subsystem(s) inoperable and not in operationi SURVEILLANCE REQUIREMENTS SR 3.8.10.1 INDIAN POINT 3 SURVEILLANCE Verify correct breaker alignments and voltage to required AC. DC. and 120 V AC vital instrument bus CVIB) electrical power distribution subsystems.

3.8.10*2 Immediately FREQUENCY 7 days Amendnent 205

' I \.J 3.9 REFUELING OPERATIONS

3.9.1 Boron

Concentration Boron Concentration 3.9.1 LCO 3.9.1 Boron concentrations of the Reactor *coolant System and the refueling cavity shall be maintained within the limit specified in the COLR. APPLICABILITY:

HOOE 6. ACTIONS CONDITION REQUIRED ACTION A. Boron concentration not A.l Suspend CORE within limit. ALTERATIONS.

Arm A.2 Suspend positive reactivity additions.

Arm A.3 Initiate action to restore boron concentration to within limit. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.1.1 Verify boron.concentration is within the limit specified in COLR. INDIAN POINT 3 3.9.1*1 COMPLETION TIME Inrnediately Inmedi ately Inrnediately FREQUENCY 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Amendment 205

3.9 REFUELING

OPERATIONS

3.9.2 Nuclear

Instrumentation Nuclear Instrumentation 3.9.2 LCO 3.9.2 Two source range neutron flux monitors shall be OPERABLE.

APPLICABILITY:

MODE 6. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required source range A.I Suspend CORE I11111ediately neutron flux monitor ALTERATIONS.

inoperable.

MID A.2 Suspend positive I11111ediately reactivity additions.

B. Two required source range B.1 Initiate action to I11111ediately neutron flux monitors restore one source range inoperable.

neutron flux monitor to OPERABLE status. MID B.2 Perform SR 3.9.1.1. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> INDIAN POINT 3 3.9.2*1 Amenctnent 205 u u SURVEILLANCE REQUIREHENTS SR 3.9.2.1 SR 3.9.2.2 INDIAN POINT 3 . SURVEILLANCE Perform CHANNEL CHECK. *******************NOTE********************

Neutron detectors are excluded from CHANNEL CALIBRATION.

• • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • -~-

Perform CHANNEL CALIBRATION.

3.9.2*2 Nuclear Instrumentation

3.9.2 FREQUENCY

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 24 months /vnenonent 205 Containment Penetrations 3.9.3 3.9 REFUELING OPERATIONS

3.9.3 Containment

Penetrations LCO 3.9.3 The containment penetrations shall be in the following status: a. The equipment hatch closed and held in place by at least four bolts or the equipment hatch opening is closed using an equipment hatch closure plate that may include a personnel access door that is capable of being closed; b. One door in each air lock is capable of being closed; c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either: 1. closed by a manual or automatic isolation valve, a blind flange, or equivalent, or 2. capable of being closed by OPERABLE Containment Purge Isolation System. -~--------------------------NOl'E----------------~~~--~~-

Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

APPLICABILITY:

During movement of recently irradiated fuel assemblies within containment.

INDJAN PO!NT 3 3.9.3-1 Amendment 215 MAR 17 2003 ___ ..,-_____ , ___ __,,,_ ----* .

u ACTIONS CONDITION A One or more containment A.1 penetrations not in required status. INDIAN POINT 3 REQUIRED ACTION Suspend movement of recently irradiated fuel assemblies within containment 3.9.3-2 Containment Penetrations

3.9.3 COMPLETION

TIME Immediately Amendment*

21.5 MAR 1 7 2003 u u Containment Penetrations

3.9.3 SURVEILLANCE

REQUIREMENTS SR 3.9.3.1 SR 3.9.3.2 INDIAN POINT 3 SURVEILLANCE FREQUENCY Verify each required containment penetration is in the 7 days required status. Verify each required containment purge system valve 92 days actuates to the isolation position on an actual or simulated actuation signal. 3.9.3-3 Amendment Zl.5 MAR 17 2003

\_) RHR and Cool ant Ci rcul ati on -High Water Level 3.9.4 3.9 REFUELING OPERATIONS

3.9.4 Residual

Heat Removal CRHR) and Coolant Circulation-High Water Level LCO 3.9.4 APPLICABILITY: "ACTIONS One RHR loop shall be OPERABLE and in operation.

---

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

The required RHR loop may not be in operation for~ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period, provided no operations are permitted that would cause reduction of the Reactor Coolant System boron concentration.

HOOE 6 with the water level 23 ft above the top of reactor vessel flange. CONDITION REQUIRED ACTION COMPLETION TIHE A. RHR loop requirements not A.1 Suspend operations Inrnediately met. involving a reduction in reactor coolant boron concentration.

MID A.2 Suspend loading Inrnediately irradiated fuel assemblies in the core. MID A.3 Initiate action to Inrnediately satisfy RHR loop requirements. (continued)

INDIAN POINT 3 3.9.4-1 .Amenanent 205 RHR and Coolant Circulation-High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION A. (continued)

A.4 Close all containment penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SR 3.9.4.1 INDIAN POINT 3 SURVEILLANCE Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of :l! 1000 gpm. 3.9.4-2 COMPLETION TIME 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> . Amendment 205 Residual Heat Removal CRHR) and Cool ant Ci rcul ati on -Low Water Level 3.9.5 3.9 REFUELING OPERATIONS

3.9.5 Residual

Heat Removal CRHR) and Coolant Circulation-Low Water Level LCO 3.9.5 Two RHR loops shall be OPERABLE, and one RHR loop shall be in operation.

APPLICABILITY:

MODE 6 with the water level< 23 ft above the top of reactor vessel flange. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A.1 Initiate action to I11111ediately number of RHR loops restore required RHR OPERABLE.

loops to OPERABLE status. QR A.2 Initiate action to I11111ediately establish~

23 ft of water above the top of reactor vessel flange. B. No RHR loop in operation.

B.1 Suspend operations Immediately involving a reduction in reactor coolant boron concentration.

Mm (continued)

INDIAN POINT 3 3.9.5-1 Amenanent 205 u Residual Heat Removal CRHR) and Cool ant Ci rcul ati on -Low Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION B. (continued)

B.2 B.3 Initiate action to restore one RHR loop to operation.

Close all containment penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 INDIAN POINT 3 SURVEILLANCE Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of ::!: 1000 gpm. Verify correct breaker alignment and indicated power available to the required RHR pump that is not in operation.

3.9.5-2 COMPLETION TIME Inrnediately 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 7 days Amendnent 205 I ' '-._/ . Refueling Cavity Water Level 3.9.6 3.9 REFUELING OPERATIONS

3.9.6 Refueling

Cavity Water Level LCO 3.9.6 Refueling cavity water level shall be maintained.~

23 ft above the top of reactor vessel flange. APPLICABILITY:

During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION A. Refueling cavity water level not within limit. SURVEILLANCE REQUIREMENTS A.1 A.2 SURVEILLANCE REQUIRED ACTION Suspend CORE ALTERATIONS.

Suspend movement of i rr adi ated fuel assemblies within containment.

SR 3.9.6.1 Verify refueling cavity water level is~ 23 ft above the top of reactor vessel flange. INDIAN POINT 3 3.9.6*1 COMPLETION TIME Inrnedi ately I nrnedi ate l y FREQUENCY 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Amenonent 205 V Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location Indian Point 3 is located on the east bank of the Hudson River at Indian Point, Village of Buchanan, in upper Westchester County, New York. The site is approximately 24 miles north of the New York City boundary line. The nearest city is Peekskill which is 2.5 miles northeast of Indian Point. The minimum distance from the reactor center line to the boundary of the site exclusion area and the outer boundary of the low population zone as defined in 10 CFR 100.3 is 350 meters and 1100 meters. respectively.

4.2 Reactor

Core 4.2.1 4.2.2 Fuel Assemblies The reactor shall contain 193 fuel assemblies.

Each assembly shall consist of a matrix of Zircalloy or ZIRLO clad fuel rods with an initial composition of natural or .slightly enriched uranium dioxide CU0 2) as fuel material.

Reload fuel will have a U*235 enrichment of s 5.0 weight percent. limited substitutions of zirconium alloy or stainless

• steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions. Control Rod Assemblies The reactor core shall contain 53 control rod assemblies.

The control material shall be silver indium cactnium, as approved by the NRC. INDIAN POINT 3 4.0-1 (continued)

Amenctnent 205 u 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: a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent: b. ke,, 0.95 if assemblies are inserted in accordance with Technical Specification 3.7.16. Spent Fuel Assembly Storage. c. A nominal 9.075 inch center to center distance between fuel assemblies placed in the high density fuel storage racks CRegi on II) : d. A nominal 10.76 inch center to center distance between fuel assemblies placed in low density fuel storage racks (Region I): 4.3.1.2 The new fuel storage racks are designed and shall be maintained with: 4.3.2 Drainage a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent: b. ke,, 0.95 under all possible moderation conditions (Credit may be taken for burnable integral neutron absorbers):

c. A nominal 20.5 inch center to center distance between fuel assemblies placed in the storage racks. The spent fuel pit is designed and shall be maintained to prevent inadvertent draining of the pool below a nominal elevation of 88 ft. (continued)

INDIAN POINT 3 4.0*2 Amendnent 205 u 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued)

4.3.3 Capacity

Design Features 4.0 The spent fuel pit is designed and shall be maintained with a storage capacity limited*to no more than 1345 fuel assemblies.

INDIAN POINT 3 4.0-3 Amenanent 205

5.0 ADMINISTRATIVE

CONTROLS 5.1 Responsibility Responsibility 5.1 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence. The plant manager or his designee shall approve. prior to implementation, each proposed test. experiment or modification to systems or equipment that affect nuclear safety. 5.1.2 The shift supervisor CSS) shall be responsible for the control room COllllland function.

During any absence of the SS from the control room while the unit is in HOOE 1. 2, 3, or 4. an individual with an a~tive Senior Reactor Operator (SRO) license shall be designated to assume the control room c011111and function.

During any absence of the SS from the control room while the unit is in HOOE 5 or 6. an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

INDIAN POINT 3 5.0*1 lwenanent 205 V 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization

5.2.1 Onsite

and Offsite Organizations Organization

5.2 Onsite

and offsite organizations shall be established for unit operation and corporate management.

respectively.

The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant. a. Lines of authority.

responsibility.

and cofllllunication shall be defined and established throughout highest management levels, intermediate levels. and all operating organization positions.

These relationships shall be documented and updated, as appropriate.

in organization charts. functional descriptions of departmental responsibilities and relationships.

and job descriptions for key personnel positions.

or in equivalent forms of documentation.

These requirements.

including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in these .Technical Specifications.

shall be documented in the FSAR and Quality Assurance Plan. as appropriate:

b. The plant manager shall be responsible for overall safe operation of _the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant: c. The corporate officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating.

maintaining.

and providing technical support to the plant to ensure nuclear safety; and d. The individuals who train the operating staff. carry out health physics. or perform quality assurance functions may report to the appropriate onsite manager: however. these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures. (continued)

INDIAN POINT 3 5.0*2 twenonent 205 Organization 5.2 5.2 Organization 5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned to each reactor containing fuel and an additional non-licensed operator shall be assigned for each control room from which a reactor is operating in MODES 1, 2, 3, or 4. b. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m}(2}(i) and 5.2.2.a and 5.2.2.f for a period of time not to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to accolllTlodate unexpected absence of on-duty shift crew members provided illlTlediate action is taken to restore the shift crew composition to within the minimum requirements.

c. A radiation protection technician shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, in order to provide for unexpected absence, provided i11111ediate action is taken to fill the required position.

d. Not Used --------.. (contiriued)

INDIAN POINT 3 5.0 -3 Amendment 240 Organization 5.2 5.2 Organization 5.2.2 *----------------------------

Unit Staff (continued)

e. The operations manager or assistant operations manager shall hold an SRO license. f. When in MODES 1, 2, 3, or 4 an individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. This individual shall meet the qualifications specified by ANSI/ANS 3.1-1993 as endorsed by RG 1.8, Rev. 3, 2000. INDIAN POINT 3 5.0 -4 Amendment 248 Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS lifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI/ANS 3.1-1978 for comparable positions with exceptions specified in the Entergy Quality Assurance Program Manual (QAPM). 5.3.2 For the purpose of 10 CFR 55.4, a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1, perform the functions described in 10 CFR 50.54(m).

INDIAN POINT 3 5.0 -5 Amendment 248

5.0 ADMINISTRATIVE

CONTROLS 5.4 Procedures Procedures 5.4 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978; b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33; c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation; and e. All programs specified in Specification

5.5. INDIAN

POINT 3 5.0 -6 Amendment 234 V (_j 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 COOCH> .a. The ODCH 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 ODCH shall also contain the radioactive effluent controls and radiological envirorvnental 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 ODCH: INDIAN POINT 3 1. Shall be documented and records of reviews performed shall be retained.

This documentation shall contain: 2. 3. Ca) Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and Cb) A determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose. or setpoint calculations:

Shall become effective after the approval of the plant manager: and Shall be submitted to the NRC*in the form of a complete, legible copy of the entire ODCH as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report (continued) 5.0*7 *1vnendment 205 V \ Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 5.5.2 Offsite Dose Calculation Manual CPDCH> (continued>

in which any change in the ODCH was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed. and shall indicate the date (i.e .* month and year) the change was implemented.

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 following:

a. Residual Heat Removal System: b. Cross Connect Between Low Head Recirculation System and High Head Safety Injection System: C. High Head Safety Injection system (partial):

d. Reactor Coolant Sampling System: e. Post Accident Containment Air Sampling System: f. Volume Control Tank (including Reactor Coolant Pump seal return line): g. Containment Hydrogen Monitoring system. The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements:

and b.

• Integrated leak test requirements for each system at refueling cycle intervals or less. (continued)

INDIAN POINT 3 5.0-8 Amencinent 205 V u 5.5.3 5.5.4 N'.JI' USED Radioactive Effluent ccntrols P:n;g;c:Aa

?=-og=a::-s a'"l.d 1"..a.~uals 5.5 nris progiam canfonrs to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to ma:rbers of the public £ran radioactive effluents as lc:M as reasonably achievable.

The progiam shall be contained in the ODCM, shall be inplsrented by procedures, and shall include rsoodial actions to be taken whenever the program limits are exceeded.

The progiam shall include the follc:Ming elements:

a. Limitations on the ftmctional capability of radioactive liquid and gaseous m:initoring instnnrentaticn including surveillance tests and setpoint determination in accordance with the zrethodology in the Orx:M; b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, canfcmning to 10 timas the concentration values in 10 CFR 20, .Appendix B, Table 2, Colunn 2; c. M:Jnitoring, sanpling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the zrethodology and pararreters in the CIXM; <continued}

INDIAN romr 3 5.0 -9 Amendrrent

~. 2 1 0 ---~--..;.L.:...-

..... _____ ------~ ..... -... ---=--

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

d. . Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I; e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at 1 east every 31 days; f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I; g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be limited to the following:

a. For noble gases: Less than or equal to a dose rate of 500 mrem/yr to the whole body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and b. For iodine-131, tritium, and for all radionuclides in particulate form with half-lives greater than 8 days: Less than or equal to dose rate of 1500 mrem/yr to any organ. h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; (continued)

INDIAN POINT 3 5.0 -10 Amendment 232 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 5.5.5 5.5.6 Radioactive Effluent Controls Program (continued)

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, tritium, and.all radionuclides in particulate form with half lives> 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluents Controls Program surveillance frequency.

Component Cyclic or Transient Limit This program provides controls to track the FSAR, Section 4.1.5, cyclic and . transient occurrences to ensure that components are maintained within the design limits. Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel.

The program shall include inspection frequencies and acceptance criteria.

The inspection frequency will ensure that each reactor coolant pump flywheel is surface and volumetrically inspected at 20-year intervals. (continued)

INDIAN POINT 3 5.0 -11 Amendment 232 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports.

The program shall include the following:

a. b. c. d. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code} and applicable Addenda as follows: ASME OM Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days 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 inservici testing activities; The provisions of SR 3.0.3 are applicable to inservice testing activities; and Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS. (continued)

INDIAN POINT 3 5.0 -12 Amendment 245 Programs and Manuals 5.5 5.5.8 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained.

In addition, the Steam Generator Program shall include the following:

a. Provisions for condition monitoring assessments.

Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged, to confirm that the performance criteria are being met. b. Performance criteria for SG tube integrity.

SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE. INDIAN POINT 3 1. Structural integrity performance criterion:

All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), all anticipated transients included in the design specification and design basis accidents.

This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials.

Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse.

In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads. 2. Accident induced leakage performance criterion:

The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the (continued) 5.0 -13 Amendment 257 5.5 5.5.8 and Manuals Steam Generator (SG) Program (continued)

Programs and Manuals 5.5 leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 0.3 gpm per SG and 1 gpm through all SGs. 3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE." c. Provisions for SG tube plugging criteria.

Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged. d. Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging criteria.

The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

2. After the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results in more frequent inspections).

In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated.

The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new INDIAN POINT 3 5.0 -14 Amendment 257 5.5 5.5.8 Steam Generator (SG) Program (continued)

Programs and Manuals 5.5 form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. a) After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b) During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c) During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d) During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods. 3. If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-line indication is not associated with a crack(s), then the indication need not be treated as a crack. e. Provisions for monitoring operational primary to secondary LEAKAGE. -------------------NOTE--------------

Pages 5.0-16 through 5.0-19 are deleted. Next page is 5.0-20. INDIAN POINT 3 5.0 -15 Amendment 257 u Programs and Manuals 5.5 5.5 Programs and Manuals 5.5:9 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation.

The program shall include: a. Identification of a sampling schedule for the critical variables and control points for these variables;

b. Identification of the procedures used to measure the values of the critical variables:

c. Identification of process sampling points. which shall include monitoring the condenser hot wells for evidence of condenser in leakage: d. Procedures for the recording and management of data; e. Procedures defining corrective actions for all off control point chemistry conditions:

and f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action. (continued)

INDIAN POINT 3 5.0-20 /wendment 205 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) This program provides controls for implementation of required testing of the ventilation filter function for the Control Room Ventilation System and Containment Fan Cooler Units. Applicable tests described in Specifi"cations 5.5.10.a, 5.5.10.b, 5.5.lO~c and 5.5.10.d shall be performed:

1) After 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of charcoal adsorber use since the last test; and, 2) Every 24 months for the Control Room Ventilation System, and Containment Fan Cooler Units; and, 3) After each complete or partial replacement of the HEPA filter train or charcoal adsorber filter; and, 4) After any structural maintenance on the system housing that could alter system integrity; and, 5) After significant painting, fire, or chemical release in any ventilation zone communicating with the system while it is in operation.

SR 3.0.2 is applicable to the Ventilation Filter Testing Program. (continued)

INDIAN POINT 3 5.0 -21 Amendment 224 u Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

a. Demonstrate for each system that an inplace test of the high efficiency particulate air (HEPA) filters shows the specified penetration and system bypass leakage when tested in accordance with the referenced standard at the flowrate specified below. Ventilation Removal Flovrate System Efficiency (cfm) Reference Standard 80\ to 120\ Control Room of design Ventilation 2: 99\ accident Regulatory Guide 1.52, Rev 2, system rate Sections c.5.a and c.5.c 80\ to 120\ of design Containment Fan 2: 99\ accident Regulatory Guide 1.52, Rev 2, Cooler Units rate Sections C.5.a and C.5.c (continued)

INDIAN POINT 3 5.0 -22 Amendment 224 u Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

b. Demonstrate for each system that an inplace test of the charcoal adsorber shows the specified penetration and system bypass leakage when tested in accordance with the referenced standard at the flowrate specified below. Ventilation Removal System Efficiency Flowrate (cfm) Reference Standard 80\ to 120\ of Control Room design Ventilation accident rate Regulatory Guide 1.52, Rev 2, System .2; 99"s Sections C.5.a and C.5.d 80\ to 120\ of Containment Fan design Regulatory Guide 1.52, Rev 2, Cooler Units .2: 99' accident rate Sections C.5.a and C.5.d (continued)

INDIAN POINT 3 5.0 -23 Amendment 224 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

c. Demonstrate for each system that a laboratory test of a sample of the charcoal adsorber shows the methyl iodide removal efficiency specified below when tested in accordance with ASTM 03803-1989, subject to clarification below, at a temperature of 86°F and a relative humidity of 95%. Methyl iodide removal ASTM 03803-1989 Ventilation System efficiency Cl a rifi cation (%): Control Room .:: 95.5 78 ft/min face velocity Ventilation System Containment Fan Cooler .:: 85 59 ft/min face velocity Units (continued)

INDIAN POINT 3 5.0 -24 Amendment 234 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

d. Demonstrate for each system that the pressure drop across the combined HEPA filters, the demisters and prefilters (if installed), and the charcoal adsorbers is less than the value specified below when tested at the flowrate specified below. Ventilation Sistem Delta P Flowrate (cfm): (inches wq) Control Room Ventilation System ~.901 of design accident 6 rate Containment Fan Cooler Units 901 of design accident 6 rate (continued)

INDIAN POINT 3 5.0 -25 Amendment 224 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Waste Gas Holdup System, the quantity of radioactivity contained in gas storage tanks, and the quantity of radioactivity contained in unprotected outdoo~ liquid storage tanks. The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure." The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures." The program shall include: a. The limits for concentrations of hydrogen and oxygen in the Waste Gas Holdup System and a surveillance program to ensure the limits are maintained.

Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion);

b. A surveillance program to ensure that the quantity of radioactivity contained in each gas storage tank shall be limited to less than the amount that would result in a whole body exposure of~ 0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and c. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies. (continued)

INDIAN POINT 3 5.0 -26 Amendment 232

\_) u Programs and Hanuals 5.5 5.5 Programs and Hanuals 5.5.12 Diesel fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established for the DG fuel oil onsite storage tanks and the DG reserve fuel oil storage tanks. The program shall include sampling and testing requirements.

and acceptance criteria.

all in accordance with applicable ASTH Standards.

The purpose of the program is to establish the following:

a. Verification of the acceptability of new fuel oil for use prior to addition to the DG fuel oil onsite storage tanks by determining that the fuel oil has: 1. Relative density within the limits of 0.83 to 0.89. 2. kinematic viscosity within the limits of 1.8 to 5.8. and 3. a clear and bright appearance with proper color bl. Verification of the acceptability of the fuel oil in the onsite storage tanks and the reserve storage tanks every 92 days by verifying that the properties of the fuel oil in the tanks, other than those addressed in item a .* are within limits for ASTH2D fuel oil. The sampling technique for the reserve storage tanks may deviate from ASTH D270-1975 in that only a bottom sample is required.

or b2. Verification of the acceptability of each new fuel addition made subsequent to the last verification made in accordance with item bl. by verifying within 31 days following the addition that the properties of the new fuel oil, other than those properties addressed in item a. are within limits for ASTH 2D fuel oil. c. Verification every 92 days that total particulate concentration of the fuel oil in the onsite and reserve storage tanks is less than or equal to 10 mg/1 when tested in accordance with ASTH D-2276, Method A-2 or A* 3. The sampling technique for the reserve storage tanks may deviate from ASTH D270*1975 in.that only a bottom sample is required. (continued)

INDIAN POIITT 3 5.0-27 hnendnent 205 u Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 5.5.13 5.5.14 Diesel Fuel Oil Testing Program (continued)

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil.Testing Program testing frequencies.

Technical Specifications CTSl Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate actninistrative controls.and reviews. b. Licensees may make changes to Bases without prior NRC approval provided the changes do not involve either of the following:

1. a change in the TS incorporated in the license: or 2. a change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59. c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR. d. Proposed changes that do not meet the criteria of Specification 5.5.13.b above shall be reviewed and approved by the NRC prior to implementation.

Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71Ce).

Safety Function Determination Program CSEPP> This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following: (continued)

INDIAN POINT 3 5.0-28 Amenctnent 205 Programs and Hanuals 5.5 5.5 Programs and Hanuals 5.5.14 Safety Function Determination Program CSEPP> (continued)

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists: c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a resuit of multiple support system inoperabilities:

and d. Other appropriate limitations and remedial or compensatory actions. A loss of safety function exists when, assuming no concurrent single. failure. a safety function assumed in the* accident analysis cannot be performed.

For the purpose of this program. a loss of safety function may exist when a support system is inoperable.

and: a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable:

or b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable:

or c. A required system redundant to the support systern(s) for the supported systems Ca) and Cb) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program. the appropriate Conditions and Required Actions of the LCO in which the loss.of safety function exists are required to be entered. (continued)

INDIAN POINT 3 5.0-29 Amendment 205 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions.

This program shall be in accordance with NEI I 94-01, Revision 2A, "Industry Guideline for Implementing Performance-Based Option of 10 CFR Part 50, Appendix J," October 2008, as modified by the following exception:

ANS 56.8-2002, Section 3.3.1: WCCPPS isolation valves are not Type C tested. The maximum allowable primary containment leakage rate, La, at a minimum test pressure equal to Pa, shall be 0.1 % of primary containment air weight per day. Pa is the peak calculated containment internal pressure related to the design basis accident.

Leakage acceptance criteria are: a. Containment leakage rate acceptance criterion is~ 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are~ 0.60 La for the Type Band C tests and~ 0.75 La for Type A tests; b. Air lock testing acceptance criteria are: 1) Overall air lock leakage rate is 0. 05 La when tested at .::: Pa, 2) For each door, leakage rate is~ 0.01 La when pressurized to.::: Pa, c. Isolation Valve Seal Water System leakage rate acceptance criterion is~ 14,700 cc/hr at.::: 1.1 Pa. d. Acceptance criterion for leakage into containment from isolation valves sealed with the service water system is~ 0.36 gpm per fan (continued)

INDIAN POINT 3 5.0 -30 Amendment 256 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 5.5.16 Containment Leakage Rate Testing Program (continued) cooler unit when pressurized at.:::. 1.1 Pa* This limit protects the internal recirculation pumps from flooding during the 12-month period of post accident recirculation.

The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 1 OCFR50, Appendix J. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is 42.38 psig. The containment design pressure is 47 psig. The maximum allowable primary containment leakage rate, La, at Pa, shall be 0.1 % of primary containment air weight per day. 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 Ventilation System (CRVS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge.

The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident.

The program shall include the following elements: (continued)

INDIAN POINT 3 5.0-31 Amendment 253 5.5.16 Control Room Envelope Habitability Program (continued)

a. The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.l 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.l and C.2 of Regulatory Guide 1.197, Revision 0. d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CRVS, 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.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph

c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analysis of OBA consequences.

Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis. f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

INDIAN POINT 3 5.0 -3la Amendment 239 Reporting Requirements 5.6 u* 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements u \ u The following reports shall be submitted in accordance with 10 CFR 50.4. 5.6.1 Not Used 5.6.2 Annual Radiological Environmental Operating Report -----------------------------NOTE-------------------------------

A single submittal may be made for a multiple unit station. The submittal should combine sections corrmon 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 surrmaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50 1 Appendix I 1 Sections IV.B.2 1 IV.B.3 1 and IV.C. (continued)

INDIAN POINT 3 5.0 -32 Amendment 227 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 5.6.3 5.6.4 5.6.5 Annual Radiological Environmental Operating Report (continued}

A full listing of the infonnation to be contained in the Annual Radiological Environmental Operating Report is provided in the ODCM. Radioactive Effluent Release Report ------------------------------NOTE------------------------------

A single submittal may be made for a multiple unit station. The submittal shall combine sections common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit. The Radioactive Effluent Release Report covering the operation of the unit in the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in confonnance with 10 CFR Part 50.36a and 10 CFR 50, Appendix I, Section IV.B.1. Not Used 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: (continued)

INDIAN POINT 3 5.0 -33 Amendment 227 u \ / -...__;* Reporting Requirements 5.6 5.6 Reporting Requirements 5-:-6. 5 CORE OPERATING LIMITS REPORT (COLR) (continued)

b. 1. Specification 2.1, Safety Limits (SL); 2. Specification 3.1.1, Shutdown Margin; 3. Specification 3.1.3, Moderator Temperature Coefficient;

4. Specification 3.1.5, Shutdown Bank Insertion Limits; 5. Specification 3.1.6, Control Bank Insertion Limits; 6. Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)); 7. Specification 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor; 8. Specification 3.2.3, AXIAL FLUX DIFFERENCE (AFD); 9. Specification 3.3.1, Reactor Protection System Instrumentation;

10. Specification 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits; and 11. Specification 3.9.1, Boron Concentration.

The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 (W Proprietary). (Specifications 3.1.5, Shutdown Bank Insertion Limits, 3.1.6, Control Bank Insertion Limits, and 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor); 2a. WCAP-8385, "POWER DISTRIBUTION CONTROL AND LOAD FOLLOWING PROCEDURES, TOPICAL REPORT," September 1974 (W Proprietary). (Specification 3.2.3, Axial Flux Difference (AFD) (Constant Axial Offset Control);

2b. 2c. T. M. Anderson to K. Kneil (Chief of Core Performance Branch, NRC) January 31, 1980 --

Attachment:

Operation and Safety Analysis Aspects of an Improved Load Follow Package. (Specification 3.2.3, Axial Flux Difference (AFD) (Constant Axial Offset Control));

NUREG-0800, Standard Review Plan, U.S. Nuclear Regulatory Commission,Section 4.3,Nuclear Design,July 1981. Branch (continued)

INDIAN POINT 3 5.0 -34 Amendment 225 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

Position CPB 4.3-1, Westinghouse Constant Axial Offset Control (CAOC), Rev. 2, July 1981. (Specification 3.2.3, Axial Flux Difference (AFD) (Constant Axial Offset Control));

3. WCAP-12945-P-A, Volume 1 (Revision

2) and Volumes 2 through 5 (Revision 1), "Code Qualification Document for Best-Estimate Loss-of-Coolant-Accident Analysis," March 1998 (Westinghouse Proprietary);

4. WCAP-11397-P-A, "Revised Thermal Design Procedure," April 1989 (Specification 2.1, Safety Limits (SL)) and Specification 3.4.1, (RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits); 5. WCAP-8745-P-A, "Design Bases for the Thermal Overpower lff and Thermal Overtemperature lff Trip Functions," September 1986 (Specification 2.1, Safety Limits (SL)); 6a. WCAP-10054-P-A, "SMALL BREAK ECCS EVALUATION MODEL USING NOTRUMP CODE," (W Proprietary). (Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)); 6b. WCAP-10054-P-A, Addendum 2, Revision 1, "Addendum to the Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code; Safety Injection into the Broken Loop and Casi Condensation Model," July 1997 (Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)));

6c. WCAP-10079-P-A, "NOTRUMP NODAL TRANSIENT SMALL BREAK AND GENERAL NETWORK CODE," (W Proprietary). (Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)));

7. WCAP-12610, "VANTAGE+

Fuel Assembly Report," (W Proprietary). (Specification 3.2.1, Heat Flux Hot Channel Factor); 8. WCAP-137 49-P-A, "Safety Evaluation Supporting the Conditional Exemption of the Most Negative EOL Moderator Temperature Coefficient Measurement," March 1997. (Specification 3.1.3, Moderator Temperature Coefficient);

9. WCAP-16045-P-A, "Qualification of the Two-Dimensional Transport Code PARAGON," August 2004. (Specification 3.1.1, Shutdown Margin, Specification 3.1.3, Moderator Temperature Coefficient, Specification 3.1.5, Shutdown Bank Insertion Limits, Specification 3.1.6, Control Bank Insertion Limits, Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)), Specification 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor, Specification 3.2.3, Axial Flux Difference (AFD), Specification 3.9.1, Boron Concentration);

and 10. WCAP-10965-P-A, "ANC: A Westinghouse Advanced Nodal Computer Code," September 1986. (Specification 3.1.1, Shutdown Margin, Specification 3.1.3, Moderator Temperature Coefficient, Specification 3.1.5, Shutdown Bank Insertion Limits, Specification 3.1.6, Control Bank Insertion Limits, Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)), Specification 3.2.2, Nuclear Enthalpy Rise Hot continued INDIAN POINT 3 5.0 -35 Amendment 261 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

Channel Factor, Specification 3.2.3, Axial Flux Difference (AFD), Specification 3.9.1, Boron Concentration).

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 for each reload cycle to the NRC. 5.6.6 NOT USED (continued)

INDIAN POINT 3 5.0 -35a Amendment 261 Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7 5.6.8 Post Accident Monitoring Instrumentation (PAM) Report When a report is required by LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the next 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. Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification

5.5.8 Steam

Generator (SG) Program. The report shall include: a. The scope of inspections performed on each SG, b. Degradation mechanisms found, c. Nondestructive examination techniques utilized for each degradation mechanism, d. Location, orientation (if linear), and measured sizes (if available) of service induced indications, e. Number of tubes plugged during the inspection outage for each degradation mechanism, f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each SG, and g. The results of condition monitoring, including the results of tube pulls and situ testing. INDIAN POINT 3 5.0-36 Amendment 257 High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20: 5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation

a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.

b.

• Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas. d. Each individual or group entering such an area shall possess: INDIAN POINT 3 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) 5.0 -37 Amendment 232 High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is* responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by mean~ of closed circuit television, of personnel qualified in radiati-0n 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 survei 11 ance.

• 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)

INDIAN POINT 3 5.0 -38 Amendment 232 High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 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

a. Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and, in addition:

1. All such door and gate keys shall be maintained under the administrative control of the shift supervisor, radiation protection manager, or his or her designee.

2. Doors and gates sha11 remain 1ocked 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 shill possess: 1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or 2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personne1 radiation exposure within the area with the means to communicate with and control every individual in the area, or (continued)

INDIAN POINT 3 5.0 -39 Amendment 232 High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 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, (i) -Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area. 4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area. e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry. (continued)

INDIAN POINT 3 5.0 -40 Amendment 232 5.7 High Radiation Area High Radiation Area 5.7 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)

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 ~hall be activated at the area as a warning device. INDIAN POINT 3 5.0 -41 Amendment 232