ML110871955

License Renewal - Appendices a, B, C, and D to the Renewed Operating License for Unit 1 (NPF-41)

ML110871955
Person / Time
Site:	Palo Verde
Issue date:	04/21/2011
From:	Regner L M License Renewal Projects Branch 2
To:
Regner L M, NRR/DLR, 415-1906
References
Download: ML110871955 (330)

Text

APPENDIX A IMPROVED TECHNICAL SPECIFICATIONS PALO VERDE NUCLEAR GENERATING STATION, UNITS 1, 2, AND 3 FACILITY OPERATNG LICENSE NO S. NPF-41, NPF-51 AND NPF

-74 ARIZONA PUBLIC SERVICE COMPANY DOCKET NOS. STN 50

-528, STN 50

-529 AND STN 50

-530

APPENDIX A T O FACILITY OPERATNG LICENSES NO. NPF

-41, NPF-51 AND NPF

-74 PALO VERDE NUCLEAR GENERATING STATION, UNITS 1, 2, AND 3 ARIZONA PUBLIC SERVICE COMPANY, ET AL DOCKET NOS. STN 50

-528, STN 50

-529 AND STN 50

-530 TECHNICAL SPECIFICATION S

PALO VERDE NUCLEAR GENERATING IMPROVED TECHNICAL TABLE OF 1.0 AND APPLI 1.1 1.2 Logical 1.3 Completion 1.4 2.0 SAFETY LIMITS 2.1 2.2 SL Viol 3.0 LIMITING CONDITION FOR OPERATION ( )

3.0 SURVEILLANCE REQUIREMENT (SR) 3.1 REACTIVITY CJNTROL 3.1.1 SHUTDOWN MARGIN (SDM) Reactor Trip Breakers 3.1.2 SHUTDOWN MARGIN Trip Breakers Closed 3.1.3 Reactivity 3.1.4 Moderator ature cient 3.1 5 Control Element Assembly (CLA) 3.1.6 Shutdown CLA Insertlon 3.1.7 Regul ing C[A I ion 3.1.8 Part Strength CEA Insertion 3.1.9 lal Test Exception ( [) SHUTDOWN MARGIN 3.1.10 STE --MODES 1 and 3.1.11 STE --Reactivity Coefficient 3.2 POWER DISTRIBUTION 3.2.1 Linear Heat 3.2.2 anar Radial Peaking Factors 3.2.3 Azimuthal Powerfilt 3.2.4 Depa re From Nucleate BOil ing Rallo 3.2.5 AXlal Shape lndex PALO VERDE NUCLEAR GENERATING IMPROVED TECHNICAL TABLE OF 3.3 Reactor Protective System (RPS) Instrumentation

--RPS Instrumentation

--Control Element Assembly Calculators RPS Logic and Trip Engineered Safety Features Actuation System (ESFAS) 3.3.6 Logic and Manual Diesel Generator (DG) -Loss of Voltage Start Containment Purge Isolation Actuation Signal Control Room Essential ltration Actuation Signal Post Accident Monitoring (PAM) Remote Shutdown Boron Dilution Alarm System 3.4 REACTOR COOLANT SYSTEM RCS Pressure, Temperature and Departure from Nucleate Boiling (DNB) RCS Minimum Temperature for RCS Pressure and Temperature (PIT) RCS Loops --MODES 1 and RCS Loops --MODE RCS Loops --MODE RCS Loops --MODE 5, Loops RCS Loops -MODE 5, Loops Not 3.4.10 Pressurizer Safety Valves --MODES 1, 2. and 3.4.11 Pressurizer Safety Valves -MODE 3.4.12 Pressurizer Low Temperature Overpressure Protection CLTOP) RCS Operational RCS Pressure Isolation Valve (PIV) RCS Leakage Detection RCS Specific Steam Generator (SG) Tube 3.5 EMERGENCY CORE COOLING SYSTEMS Safety Injection Tanks (SITs) S ECCS --ECCS --Refueling Water Tank Trisodium Phosphate PALO VERDE UNITS 1. i i AMENDMENT NO. +/-+/-+, 161 PALO VERDE NUCLEAR GENERATING IMPROVED TECHNICAL TABLE OF 3.6 CONTAINMENT 3.6.1 3.6.2 Containment Air 3.6.3 Containment Isolation 3.6.4 Containment 3.6.5 Containment Air 3.6.6 Containment Spray 3.7 PLANT 3.7.1 Main Steam Safety Valves 3.7.2 Main Steam Isolation Valves 3.7.3 Main Feedwater Isolation Valves 3.7.4 Atmospheric Dump Valves 3.7.5 Auxiliary Feedwater (AFW) 3.7.6 Condensate Storage Tank 3.7.7 Essential Cooling Water (EW) 3.7.8 Essential Spray Pond System 3.7.9 Ultimate Heat Sink 3.7.10 Essential Chilled Water ( ) 3.7.11 Control Room Essential ltration (CREFS) 3.7.12 Control Room Emergency Air Temperature Control System 3.7.13 Engineered Safety Feature ( ) Pump Room Exhaust Air System 3.7.14 Fuel Storage Pool 3.7.15 Fuel Storage Pool Boron 3.7.16 Secondary Specific 3.7.17 Spent Fuel Assembly 3.8 ELECTRICAL POWER 3.8.1 AC Sources --

3.8.2 AC Sources --

3.8.3 Diesel Fuel Oil. Lube Oil and Starting 3.8.4 DC Sources --

3.8.5 DC Sources --

3.8.6 Battery Cell 3.8.7 Inverters

--

3.8.8 Inverters --

3.8.9 Distribution Systems 3.8.10 Distribution Systems --

PALO VERDE UNITS 1.2.3 iii AMENDMENT NO. +/-+/-7 PALO VERDE NUCLEAR GENERATING IMPROVED TECHNICAL TABLE OF 3.9 REFUELING 3.9.1 Boron 3.9.2 Nuclear 3.9.3 Containment 3.9.4 Shutdown Cooling (SOC) and Coolant Circulation

-High Water 3.9.5 Shutdown Cooling (SOC) and Coolant Circulation

-Low Water 3.9.6 Refueling Water Level Fuel 3.9.7 Refueling Water Level --4.0 IGN 4.1 Si 4.2 Reactor 4.3 Fuel 5.0 ADMINISTRATIVE 5.1 5.2 5.3 Unit Staff 5.4 5.5 Programs and 5.6 Reporting 5.7 High Radiation PALO VERDE UNITS 1,2,3 iv AMENDMENT NO.

Defini ons l.1 1.0 1.1 USE AND APPLICATION Defini ons --------------------

NOTE---------The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases. AXIAL SHAPE INDEX AZIMUTHAL POWER CT qCHANNEL Definition ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times. ASI shall be the power generated in the lower half of the core less the power generated in the upper half of the core. divided by the sum of the power generated in the lower and upper halves of the core. lower -upper ASI lower + upper AZIMUTHAL POWER TILT shall be the power asymmetry between azimuthally symmetric fuel assemblies.

A CHANNEL CALIBRATION shall be the adjustment.

as necessary.

of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors.

The CHANNEL CALIBRATION shall encompass the entire channel. including the required sensor. alarm. display. and trip functions.

and shall include the CHANNEL FUNCTIONAL . Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. 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 recently installed sensing element. (continued)

PALO VERDE UNITS 1.2.3 1.1-1 AMENDMENT NO.

Definitions 1.1 1.1 nitions CHANNEL CALIBRATION (continued)

CHANNEL CHECK CHANNEL FUNCTIONAL TEST The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, 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 other indications or status derived from independent instrument channels measuring the same parameter.

A CHANNEL FUNCTIONAL shall be: Analog and bistable channels -the injection of a simulated or actual signal into the channel as close to the sensor as practicable to veri fy OPERABI LITY, "j nc 1 udi ng requi red alarms, interlocks.

display and trip functions; Digital computer channels -the use of diagnostic programs to test digital computer hardware and the injection of simulated process data into the channel to verify OPERABILITY.

including alarm and trip functions. CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested. (continued)

PALO VERDE UN 1.2.3 1.1-2 AMENDMENT NO. 117 Defi niti ons 1.1 1.1 Definitions (continued)

CORE ALTERATION CORE OPERATING LIMITS REPORT (COLR) DOSE EQUIVALENT I 131 AVERAGE DISINTEGRATION ENERGY CORE ALTERATION shall be the movement or manipulation of any fuel. sources. or reactivity control components

[excluding control element assemblies (CEAs) withdrawn into the upper guide structureJ.

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 limi 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.

DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132. 1-133, 1-134. and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in ICRP 30. Supplement to Part 1, page 192-212. Table titled, "Committed Dose Equivalent in Target Organs or ssues per Intake of Unit Acti vity. II E shall be the average (weighted in proportion to the concentration of each radionuclide in the reactor coolant at the time of sampling) of the sum of the average beta and gamma energies per disintegration (in MeV) for isotopes, other than iodines, with half lives> 15 minutes, making up at 1 95% of the total noniodine activity in the coolant. (continued)

PALO VERDE UNITS 1.2,3 1.1-3 AMENDMENT NO. 117 Defi niti ons 1.1 1.1 Definitions (continued)

ENGINEERED SAFETY FEATURE ( ) RESPONSE TIIVIE LEAKAGE The ESF RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i .e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable.

The response time may be measured by means of any series of sequential.

overlapping, or total steps so that the entire response time is measured.

In lieu of measurement.

response me may be verified for selected components provided that the components and methodology for veri cation have been previously reviewed and approved by the NRC. is the K effective calculated by considering the actual CEA configuration and assuming that the fully or partially inserted full strength CEA of highest worth is fully withdrawn.

LEAKAGE shall be: a. Identi fi ed LEAKAGE 1. LEAKAGE. such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water injection or leakoff).that is captured and conducted to collection systems or a sump or collecting tank; 2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not be pressure boundary LEAKAGE: or Reactor Coolant System (RCS) LEAKAGE through a steam generator (SG) to the Secondary System (primary to secondary LEAKAGE) . (continued)

PALO VERDE UNITS 1.2.3 1.1 4 AMENDMENT NO. 161 Definitions 1.1 1.1 nitions LEAKAGE (continued)

MODE NEUTRON RATED THERMAL POWER (NRTP) OPERABLE OPERABILITY PHYSICS b. Unidentified LEAKAGE All LEAKAGE 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 MODE shall correspond to anyone inclusive combination of core reactivity condition.

power level. cold leg reactor coolant temperature.

and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel. indicated neutron flux RTP. 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 reactor core and related instrumentation.

These tests are: Described in Chapter 14, Initial Test Program of the UFSAR; Authorized under the provisions of 10 CFR 50.59; or Otherwise approved by the Nuclear Regulatory Commission. (continued)

PALO VERDE UNITS 1.2,3 1.1-5 Definitions 1.1 1.1 Definitions (continued)

PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) RATED THERMAL POWER (RTP) REACTOR PROTECTIVE SYSTEM (RPS) RESPONSE TIME SHUTDOWN MARGIN (SDM) The PTLR is the site specific document that provides the reactor vessel pressure and temperature limits. including heatup and cooldown rates, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.9. RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3990 MWt. The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until electrical power to the CEAs drive mechanism is interrupted.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC. SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All full strength CEAs (shutdown and regulating) are fully inserted except for the single CEA of highest reactivity worth, which is assumed to be fully withdrawn.

With any full strength CEAs not capable of being fully inserted, the withdrawn reactivity worth of these CEAs must be accounted for in the determination of SDM and b. There is no position.

change in part strength CEA PALO VERDE UNITS 1,2,3 1.1-6 AMENDMENT NO. +/-+g, 179 Defi niti ons 1.1 1.1 Definitions (continued)

STAGGERED TEST BASIS THERMAL POWER A STAGGERED TEST BASIS sllall consist of the testing of one of the systems, subsystems.

channels, or other designated components during the interval specified by the Surveillance Frequency.

so that all systems. subsystems.

channels.

or other designated components are tested during n Surveillance Frequency intervals.

where n is the total number of systems.subsystems.

channels, or other designated components in the associated function.

THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant. PALO VERDE UNITS 1.2.3 1.1-7 AMENDMENT NO.

Defi niti ons 1.1 Table 1.1 1 (page 1 of 1)MODES MODE TITLE REACTIVITY CONDI ON ( k eff ) %RATED POWER a COLD LEG TEMPERATURE (OF) 1 Power Operation

0.99 > 5 NA 2 Startup ;

:: 0.99 :5 5 NA 3 Hot Standby < 0.99 NA 350 4 Hot Shutdown Cb ) < 0.99 NA 350 > Tcold > 210 5 Cold Shutdown Cb ) < 0.99 NA :5 210 6 Refueling CC ) NA NA NA Ca) Excluding decay heat. (b) All reactor vessel head closure bolts fully tensioned. (c) One or more reactor vessel head closure bolts less than fully tensioned.

PALO VERDE UNITS 1.2.3 1.1 8 AMENDMENT NO.

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors The purpose of this section 1S 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 are AND and OR. The physical arrangement of these connectors constituteS-logical conventions with specific meanings.

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

When logical connectors are used to state a Condition, Completion Time. Surveillance.

or Frequency, only the first level of logic used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

PALO VERDE UNITS 1,2,3 1.2 AMENDMENT NO.

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1. 1 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.l Verify ... AND A.2 Restore. . . In this example the logical connector AND is used to indicate that when in Condition A, botn-Required Actions A.l and A.2 must be completed.

PALO VERDE UNITS 1,2,3 1. 2-2 AMENDMENT NO.

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip OR A.2.1 Verify AND A.2.2.1 Reduce OR A.2.2.2 Perform OR A.3 Align This example represents a more complicated use of logical connectors.

Required Actions A.1. A.2.

and A.3 are alternative choices. only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement.

Anyone of these three Actions may be chosen. If A.2 is chosen. then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by perform-ing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative cnoices. only one of which must be performed.

PALO VERDE UNITS 1.2.3 1. 2-3 AMENDMENT NO.

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use. BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCD 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 Condi on unless otherwise specified.

providing the unit is in a MODE or specified condition stated in the Applicability of the LCD. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in and the Required Actions apply until the Condition no longer exists or the unit is not within the LCD 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 Condi ons, separate Completion Times are tracked for each Condition starting from the time discovery of the situation that required entry into the Condition.

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

or variables expressed in the Condition.

discovered to be inoperable or not within limits. will not result in separate entry into the Condition.

unless specifiCally stated. The Required Actions of the Condition continue to to each additional failure. with Completion Times based on initial entry into the Condition. (continued)

PALO VERDE UNITS 1.2,3 1.3 AMENDMENT NO.

Completion Times 1.3 Completion Times DESCRI PTION (continued)

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 T-ime extension.

two criteria must first be met. The subsequent inoperability: Must exist concurrent with the first inoperability;Must remain inoperable or not within limi after the first inoperability is resolved.

The total Completion me allowed for compl ng a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either' The stated Completion Time. as measured from the initial entry into the Condition.

plus an additional 24 hours1 days <br />0.143 weeks <br />0.0329 months <br />; or The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train. subsystem.

component.

or variable expressed in the Condition) and separate tracking of Compl on Times based on this re-entry.

These exceptions are stated in individual The above Completion Time extension does not apply to Completion me with a modified "time zero." This "time zero" may be expressed as a repetitive time (i .e .. "once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br />." where the Completion Time is referenced a previous completion of the Required Action versus the of Condition entry) or as a time modified by the phrase"from discovery

..." Example 1.3-3 illustrates one use of type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

PALO VERDE UNITS 1,2,3 1. AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times (continued)

The following examples illustrate the use of Completion Times with different types of Conditions and changing Condi ons.

1. 3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and associated Completion me not B.l Be in MODE 3. AND B.2 Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> met. Condition B has two Required Actions. Each Required Action has i own separate Compl on Time. Each Completion Time is referenced to the time that Condition B is entered. The Required Actions of Condition B are to be in MODE 3 within 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> AND in MODE 5 within 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br />. A total of 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> is allowed for reaching MODE 3 and a total of 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> (not 42 hours1.75 days <br />0.25 weeks <br />0.0575 months <br />) is allowed for reaching MODE 5 from the me that Condition B was entered. If MODE 3 is reached within 3 hours0.125 days <br />0.0179 weeks <br />0.00411 months <br />. the time allowed for reaching MODE 5 is the next 33 hours1.375 days <br />0.196 weeks <br />0.0452 months <br /> because the total time allowed for reaching MODE 5 is 36 If Condition B is entered while in MODE 3, the time for reaching 5 is the next 36 PALO VERDE UNITS 1,2,3 AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1. 2 (cont'j nued) ACTIONS CONDITION REQUIRED COMPL A. One pump inoperable.

A.l Restore pump to OPERABLE status. 7 days B. Required Action and associated Completion Time not met. B.l Be in MODE 3. AND B.2 Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 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.l and B.2 start. If the inoperable pump is restored to OPERABLE status Condition B is entered, Condition A and B are exited. and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable.

Condition A is not re-entered for the second pump. LCO 3.0.3 is entered. since the ACTIONS do not include a Condition for more than one inoperable pump.The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered. but continues to be tracked from the time Condition A was initially entered. While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

PALO VERDE UNITS 1.2.3 1.3-4 AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

While in LCO 3.0.3. if one of the inoperable pumps is restored to OPERABLE status and the Compl on Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condi on B. The Completion Time for Condi on B is tracked from the time the Condition A Completion Time expired. On restoring one of the pumps to OPERABLE , the Condition A Completion Time is not , 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.

PALO VERDE UNITS 1.2,3 1.3 5 AMENDMENT NO.

Completion mes 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3 3 (continued)

ACTIONS A. CONDITION One Function X train inoperable.

REQUIRED ACTION A.l Restore Functi on X tra'j n to OPERABLE status. COMPLETION TIME 7 days AND-10 days from discovery failure to meet the LCO B. One Function Y train inoperable.

B.1 Restore Function Y train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> AND -10 days from discovery of failure to meet the LCO C. One Function X train inoperable.

AND -One Function Y train inoperable.

C.l Restore Function X train to OPERABLE status. OR -C.2 Restore Function Y train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> PALO VERDE UN 1.2,3 1.36 AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3 3 (continued)

When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable.

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

If Required Action C.2 is completed within the specified Completion me, Conditions Band C are exited. If the Completion Time for Required Action A.l has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i .e., initial entry into Condition A). The Completion Times of Conditions A and B are modified by a logical connector, with a separate 10 day Completion me measured from the time it was discovered the LCD 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 LCD. The separate Completion Time modified by the phrase "from di scovery fail ure to meet the LCD" is desi gned to prevent indefinite continued operation while not meeting the LCD. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock." In this instance, the Completion me "time zero" is specified as commencing at the time the LCD was initially not met, instead of at the time the associated Condition was entered.

PALO VERDE UNITS 1.2,3 1.3-7 AMENDMENT NO.

Completion Times l.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more valves inoperable.

A.1 Restore valve(s) to OPERABLE status. 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> B. Required Action and associated Completion Time not met. B.1 Be in MODE 3. AND -B.2 Be in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 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 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> provided this does not result in any subsequent valve being inoperable for> 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br />. If the Completion Time of 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> (including the extension) expires while one or more valves are still inoperable.

Condition B is entered.

PALO VERDE UNITS 1.2.3 l.3-8 AMENDMENT NO. 117 Completion mes 1.3 1.3 Completion mes EXAMPLES EXAMPLE 1.3-5 ---------------------NOTE---------

Separate Condition entry is allowed for each inoperable valve. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more valves inoperable.

A.1 Restore valve to OPERABLE status. 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> B. Required Action and associated Completion Time not met. B.1 Be in MODE 3. AND-B.2 Be in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 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.

PALO VERDE UNITS 1.2.3 1.3-9 AMENDMENT NO.

Completion mes 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires. Condition B is entered for that valve. If the Completion Times associ with subsequent valves in Condition A exp-ire. Condition B is entered separately for each valve and separate Compl on Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve. Since the Note in this example allows rnult-iple Condition entry and tracking of separate Cornpletion Times, Completion Time extensions do not apply. EXAMPLE 1.3 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel inoperable.

B. Required Action and associated Cornpletion A.l OR -A.2 6.1 Perforrn SR 3.x.x.x. Reduce THERMAL POWER to :::; 50% RTP. Be in MODE 3. Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> rne not met.

PALO VERDE UNITS 1.2.3 1.3 10 AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 Entry into Condition A offers a choice between Required Action A.l or A.2. Required Action A.l 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.l begins when Condition A is entered and the initial performance of Required Action A.l must be compl 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.l is followed and the Required Action is not met within the Completion me (plus the extension allowed by SR 3.0.2). Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> is not met, Condition B is entered. If after entry into Condition B, Required Action A.l or A.2 is met, Condition B is exited and operation may then continue in Condition A.

PALO VERDE UNITS 1,2,3 1.3-11 AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION A. One subsystem inoperable.

A.1 AND-A.2 Verify affected subsystem isolated.

Restore subsystem to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND-Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> thereafter 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Required Action and associated Completion Time not met. B.1 AND -B.2 Be in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> Required Action A.I 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 me begins at the time the Condition is entered and each "Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> thereafter" interval begins upon performance of Required Action A.1. If after Condition A is entered. Required Action A.1 is not met within ther the initial 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or any subsequent 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered.

PALO VERDE UNITS 1,2.3 1.3 12 AMENDMENT NO.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3 7 (continued)

The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.l is met after Condition B is entered. Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired. IMMEDIATE When "Immediately" is used as a Completion Time, the COMPLETION TItvlE Required Action should be pursued without delay and in a controlled manner. PALO VERDE UN 1.2,3 1. 3-13 AMENDMENT NO.

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements. Each Surveillance Requirement (SR) has a speci ed Frequency in which the Surveillance must be met in order to meet the associated LCD. 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, Reql.rirement (SR) Applicability.

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

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 LCD 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.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified.

In these examples.

the Applicability of the LCD (LCD not shown) is MODES 1. 2. and 3.

PALO VERDE UNITS 1.4-1 AMENDMENT NO. +/-+/-+

Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1. 4-1 SURVEILLANCE REQUIREMENTS FREQUENCY SURVEILLANCE 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> Perform CHANNEL CHECK. Examp 1 e 1. 4-1 contai ns the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours0.5 days <br />0.0714 weeks <br />0.0164 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 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br />. an extension of the time interval to 1. 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 LCD). 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 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 LCD 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 prior to entry into the MODE or other specified condition.

as modified by SR 3.0.3, or the LCD is considered not met (in accordance with SR 3.0.1) and LCD 3.0.4 becomes applicable.

PALO VERDE UNITS 1.2.3 1. 4-2 NO. W. 165 Frequency 1.4 1.4 Frequency EXAMPLES (cont-inued)

EXAM P LEI. 4 -2 SURVEILLANCE REQUIREMENTS SURVEILLANCE Verify flow is within Once within 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after 25% RTP AND 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> thereafter Example 1.4-2 has two Frequencies.

The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to 25% RTP, the Surveillance must be performed within 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br />. The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the extension allowed by SR 3.0.2. "Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i .e., the "once" performance -in this example).

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

PALO VERDE UNITS 1,2,3 1.4-3 AMENDMENT NO.

Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4 3 SURVEILLANCE REQUIREMENTS

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NOTE Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after 25% RTP. Perform channel adjustment.

7 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 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after power reaches 25% RTP to perform the Surveillance.

The Surveillance is still considered to be performed within the "specifi ed Frequency." Therefore.

if the Survei 11 ance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval.

but operation was < 25% RTP, it would not constitute a failure of the SR or failure to meet the LCD. Also, no violation of SR 3.0.4 occurs when changing MODES. even with the 7 day Frequency not met. provided operation does not exceed 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> with power 25% RTP. Once the unit reaches 25% RTP. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> would be allowed for completing the Surveillance.

If the Surveillance were not performed within this hour 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. PALO VERDE UNITS 1.2.3 1. 4-4 AMENDMENT NO.

2.0 SLs 2.0 LIMITS (SLs) 2.1 2.1.1 Reactor Core SLs 2.1.2 2.1.1.1 In MODES 1 and 2, Departure from Nucleate Boiling Ratio (DNBR) shall be maintained 1.34. 2.1.1.2 In MODES 1 and 2. the peak centerline temperature shall be maintained

< 5080°F (decreasing by 58°F per 10.000 MWD/MTU burnup and adjusting for burnable poisons per CENPD-382 P-A). Reactor Coolant System (RCS) Pressure SL In MODES 1. 2, 3, 4, and 5, the RCS -::; 2750 psia. sure shall be maintained 2.2 SL Violations If SL 2.1.1.1 or SL 2.1.1.2 is viol . 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 f SL 2.1 2 is violated: 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 In MDDE 3. 4. or 5. res compliance within 5 minutes. PALO VERDE UNITS 2.0-1 AMENDMENT NO . .f4B 183 LCD Applicability 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCD LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCD 3.0.2, LCD 3.0.7, and LCO 3.0.S. LCD Upon discovery of a failure to meet an the Required Actions of the associated Conditions shall be met. except as provided in LCO 3.0.5 and LCD 3.0.6. If the LCD is or is no longer applicable prior to expiration of speci ed Completion Time(s). compl on of the Required Action(s) is not required, unless otherwise stated. LCO 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: MODE 3 with-j n 7 hours0.292 days <br />0.0417 weeks <br />0.00959 months <br />; MODE 5 within 37 hours1.542 days <br />0.22 weeks <br />0.0507 months <br />. Exceptions to this Speci cation are stated in the individual Specifications.

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

LCO 3.0.3 is applicable in MODES 1, 2, 3, and 4. LCO When an LCO is not met, entry into a MODE or other speci ed condition in the Applicability shall only be made: When the associated ACTIONS to be entered permit continued operation in the MODE or other specifi condition in the Applicability for an unlimited period of time; (continued)

PALO VERDE UNITS 3.0 1 AI"lENDMENT NO. 170 3.0 LCO 3.0 LCO LCO 3.0.4 (continued)

b. After performance of a risk assessment addressing inoperable systems and components.

consideration of the results. determination of the acceptability of entering the MODE or other specified condition in the Applicability.

and establishment of risk management actions. if appropri ; 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 condi ons in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. LCO Equipment removed from or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment.

This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO When a supported system LCO is not met sol y 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 5.5.15. "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exi 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)

PALO VERDE UNITS 3.0 2 AMENDMENT NO. +/-+/-7.

LCD Applicability 3.0 LCD APPLICABILITY (continued)

LCD 3.0.6 When a support system's Required Action directs a supported (continued) 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 LCD 3.0.2. LCD 3.0.7 ial test exception (STE) LCOs in each applicable LCO section allow specified Technical Specifications (TS)requirements to be changed to permit performance of special ts and operations.

Unless otherwise specified, all other requirements remain unchanged.

Compliance with STE LCOs is optional.

When an LCO is desired to be met but is not met, the ACTIONS of the STE LCO shall be met. When an LCO is not desired to be met, entry into a MODE or other specified condition "in the Applicability shall only be made in accordance with the other applicable Specifications.

LCO 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: the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multi p 1 e tra"j n 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 hours3 days <br />0.429 weeks <br />0.0986 months <br />; or b. the not able to perform their associated support functions(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 hours. At the end of the specified period the required snubbers must be able to perform their associated support function(s).

or the affected supported system LCO(s) shall be declared not met. PALO VERDE UNITS 3.0 3 AMENDMENT NO. +/-+/-+,

SR App1 i cabil ity 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other speci ed conditions in the Applicabllity 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 LCD. lure to perform a Surveillance within the specified Frequency shall be lure to meet the LCD except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits. SR 3.0.2 The speci Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval speci ed in the Frequency.

as measured from the previous performance or as measured from the time a specified condition of the Frequency is For Frequencies specified as "once." the above extension does not If a Compl on me requires periodic performance on "once per ... " basis. the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications. . SR 3.0.3 If it is discovered that a Surveillance was not performed within i specified Frequency.

then compliance with the requirement to declare the LCD not met may be delayed. from the time of discovery, up to 24 hours1 days <br />0.143 weeks <br />0.0329 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 hours1 days <br />0.143 weeks <br />0.0329 months <br /> and the risk impact shall be managed. If the Surveillance is not performed within the delay period. the LCD must immediately be declared not met. and the applicable Condition(s) must be entered. (continued)

PALO VERDE UNITS 1.2,3 3.0-4 AMENDMENT NO.

3.0 SR 3.0 SR SR 3.0.3 When the Surveillance is performed within the delay period (continued) and the Surveillance is not met. the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. SR 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 or other speci ed 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. PALO VERDE UNITS 3.0 5 AMENDMENT NO. .

SDM -Reactor Trip Breakers Open 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) -Reactor Trip Breakers Open LCO 3.1.1 SDM shall be the value in the COLR. APPLICABILITY:

MODES 3. 4. and 5 with the Reactor Trip Breakers Open or the CEA drive system not capable of CEA withdrawal.

ACTIONS CONDI ON REQUIRED ACTION COMPLETION TIME A. SDM not within l-imit. A.l Initiate boration to restore SDM to within 1 imit. 15 minutes SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is the value in the COLR. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> PALO VERDE UNITS 1,2,3 3.1.1 1 AMENDMENT NO.

SDM -Reactor Trip Breakers Closed 3.1. 2 REACTIVITY CONTROL SYSTEMS 3.1.2 SHUTDOWN MARGIN (SDM) -Reactor Trip Breakers Closed 3.1. 2 Reactivity shall be controlled by: a. SDM shall be the value in the COLR. b. shall be < 0.99 when Tc 500°F.KNI Reactor criticality shall not be achieved with shutdown group CEA movement.

APPLICABILITY:

MODES 3, 4, and 5 with the Reactor Trip Breakers Closed and the CEA drive system capable of CEA withdrawal.

ACTIONS CONDITION REQUIRED ACTION COrvlPLETION TIME A. SDM not within limit . A.1 Initiate boration to restore SDM to within limit . 15 minutes B. KNI not within limit when Tc 500°F. OR -Reactor criticality can be achieved by shutdown group CEA movement.

B.1 AND -B.2 Vary CEA position to restore withi n l*jmits. Initiate boration to restore withi n l-j mits. 15 minutes 15 minutes PALO VERDE UNITS 1,2,3 AMENDMENT NO.

SDM Reactor Trip Breakers Closed 3.1. 2 SURVEILLANCE REQUIREMENTS SR 3.1. 2.1 SURVEILLANCE Verify SDM is 2:the value in the COLR. FREQUENCY 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SR 3.1. 2.2 Only required if Tc S 500°F. Veri fy K N , < 0.99. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SR 3.1. 2.3 Verify criticality cannot be achieved with shutdown group CEA movement.

24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> PALO VERDE UNITS 1.2.3 3.1.2-2 AMENDMENT NO.

Reactivity Balance 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Reactivity Balance 3.1.3 The core reactivity balance shall be within +/- 1%

of predicted values. APPLICABILITY:

MODE 1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity balance not within 1 i mit. A.l AND-Re-evaluate core design and safety analysis and determine that the reactor core is acceptable for continued operation.

7 days A.2 Establish appropri operating restrictions and SRs. 7 days B. Required Action and associated Completion Time not met. B.l Be in MODE 2. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1.2.3 3.1.3 AMENDMENT NO.

3.1.3 SR 3.1.

The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading. Verify overall core reactivity balance is within +/- 1.0% Ak/k of predicted values. Reactivity Balance IREMENTS SURVEILLANCE FREQUENCY Prior to ring MODE 1 fuel loading AND Only requi red after 60 EFPD PALO VERDE UN 1,2.3 AMENDMENT NO.

MTC 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Moderator Temperature Coefficient LCO 3.1.4 The MTC shall be maintained within the limits specified the COLR. and a maximum positive limit that varies linearly from 0.5 E-4 Ak/k/oF at 0% RTP to 0.0 Ak/k/oF at 100% RTP. APPLICABILITY:

MODES 1 and 2. ACTIONS REQUIRED ACTION COMPLETION TIME CONDITION 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> A. MTC not within limits. A.1 Be i n l"lODE 3. SURVEILLANCE SR -------------

--NOTE-----------This Surveillance is not required to be performed prior to entry into MODE 2. Verify MTC is within the upper limit specified in the COLR.

Prior to entering MODE 1 after each fuel loading PALO VERDE UNITS 1.2.3 3.1.4-1 AMENDMENT NO.

3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.1.4.2 ---------NOTES-----

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This Surveillance is not required to be performed prior to entry into MODE 1 or 2. If the MTC is more negative than the COLR limit when extrapolated to the end of cycle, SR 3.1.4.2 may be repeated.

Shutdown must occur prior to exceeding the minimum allowable boron concentration at which MTC is projected to exceed the lower limit. Verify MTC is within the lower limit specified in the COLR.

Each fuel cycle within 7 effective power days (EFPD) of reaching 40 EFPD core burnup AND fuel cycle withi n 7 EFPD of reachinq of expectea J core burnup PALO VERDE UNITS 1,2,3 AMENDMENT NO.

CEA Alignment 3.1. 5 3.1 REACT:VITY CONTROL SYSTEMS 3.1.5 Control Element Assembly ) Alignment LCD All full strength CEAs shall be OPERABLE.

and all full strength and part strength CEAs shall be aligned to within 6.6 inches (indicated position) of all other CEAs in their respective groups.

MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION ME A. One or more CEAs trippable and misaligned from i group by > 6.6 inches and::;: 9.9 i OR One CEA ppable and misaligned from i group by > 99 inches. A.l AND A.2 Reduce THERMAL POWER In accordance with the limlts in the COLR. Restore CEA alignment.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> nued) PALO VERDE UNITS 3.1.5-1 AMENDMENT NO. 179 CEA Alignment 3.l. 5 ACTIONS (continued)

COND ON REQUI RED ACTI ON COMPLETION TIME B. Only one CEA position indicator channel OPERABLE for one CEA per CEA Group. B.l Restore at least two position indicator channels to OPERABLE status. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> OR-B.2 Verify the CEA Group(s) with the inoperable position indicators are fully withdrawn or fully inserted while maintaining the i nserti on 1 i mi of LCO 3.1.6. LCO 3.1.7 and LCO 3.l.8. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> AND-Once per hours thereafter.

C. Required Action and associated Completion Time of Condition A or B not met OR -One or more full strength CEAs untrippable.

C.l Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> D. Two or more CEAs trippable and misaligned from their group by > 9.9 inches. D.l Open the reactor trip breakers.

Immediately PALO VERDE UN 1.2.3 3.l.5-2 AMENDMENT NO. .

CEA Alignment 3,1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3,1. 5,1 Verify the indicated position of each full strength and part strength CEA is within 6,6 inches of all CEAs in its g 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3,1. 5,2 Verify that, for each CEA, its OPERABLE position indicator channels indicate within 5,2 inches of each other, 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3,1. 5,3 Verify full strength CEA freedom of movement Ctrippability) by moving each lndividual full strength CEA that is fully inserted in core at least 5 lnches, 92 days SR 3.1. 5,4 Perform a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel. 18 months SR 3,1.5,5 Verify each full strength CEA drop me ::;: 4,0 seconds, Pn or to reactor criti cal ity, after each removal of the reactor head PALO VERDE UN 1. 2,3 3,1.5-3 AMENDMENT NO, ,

Shutdown CEA Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Shutdown Control ement Assembly (CEA) Insertion Limits LCO 3.1. 6 All shutdown CEAs shall be withdrawn to ;;::: 147. inches. APPLICABILITY:

MODE 1. MODE 2 with any regulating CEA not fully inserted. --------------

NOTE------

---

This LCO is not applicable while perform-ing SR 3.1.5.3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One shutdown CEA not within limit. A.1 Restore shutdown CEA to within 1 imit. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> B. Required Action and associated Completion me not met. B.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1,2,3 3.1.6-1 AMENDMENT NO. ++/-7.

Shutdown CEA Insertion Limits 3.1. 6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify each shutdown CEA is withdrawn 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> 147.75 inches. PALO VERDE UNITS 1,2,3 3.1.6-2 AMENDMENT NO. +/-+/-7.

Regulating CEA Insertion Limits 3.1. 7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Regulating Control Element Assembly (CEA) Insertion Limits LCO 3.1.7 The power dependent insertion limit (POlL) alarm circuit shall be OPERABLE, and with the Core Operating Limit Supervisory System (COLSS) in service or with COLSS out of service, the regulating CEA groups shall be limited to the withdrawal sequence and insertion limits specified in the COLR and the associated time restraints.

APPLICABILITY:

MODES 1 and 2. -----------------------

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

This LCO is not applicable while conducting SR 3.1.5.3 or for up to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> following a reactor power cutback operation. CONDITION REQUIRED ACTION COMPLETION TIME A. Regulating CEA groups A.l Restore regulating 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> -j nserted beyond the CEA groups to within transient insertion 1 imits. limit with COLSS in service or with COLSS OR out of service. A.2 Reduce THERMAL POWER 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> to less than or equal to the fraction of RTP allowed by the CEA group position and insertion limits specified in the COLR.

PALO VERDE UNITS 1,2,3 3.1.7-1 AMENDMENT NO.

Regulating CEA Insertion limits 3.l. 7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Regulating CEA groups inserted between the short term steady state insertion limit and the transient insertion limit for > 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> per 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> interval with COlSS in service or with COlSS out of service. B.l Restrict increases in THERI'v1Al POWER to 5% RTP per hour. minutes C. Regulating CEA groups inserted between the long term steady state insertion limit and the transient insertion limit for intervals

> 5 effective full power days (EFPD) per 30 EFPD interval or > 14 EFPD per 365 EFPD interval with COlSS in service or with COlSS out of service. C.l Restore regulating CEA groups to within limits. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> D. POll alarm circuit inoperable.

0.1 Perform SR 3.1.7.1. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND -Once per 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> thereafter E. Required Actions and associated Completion Times not met. E.l Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1,2,3 3.l.7-2 AMENDMENT NO.

Regulating CEA Insertion limits 3.l. 7 SURVEIllANCE REQUIREMENTS SURVEIllANCE FREQUENCY SR 3.l. 7.1 This Surveillance is not required to be performed prior to entry into MODE 2. Verify each regulating CEA group position is within i insertion limits. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.1. 7.2 Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SR 3.1. 7.3 Verify POll alarm circuit is OPERABLE.

31 days PALO VERDE UN ITS 1.2.3 3.l.7-3 AMENDMENT NO.

Part rength CEA Insertion mits 3.1. 8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Part Strength Control Element Assembly ) Insertion Limits LCD 3.1. 8 part strength CEA groups 11 be limited to the insertion limits specif1ed in COLR. APPLICABILITY:

MODES 1 and 2. ACTIONS REQUIRED ACTION TIME A. Part strength groups inserted beyond the transient i nserti on 11 nll t. A.1 OR A.2 Restore pa rength CEA groups within the 1 imit. Reduce THERMAL POWER to less than or equal to that fraction of RTP specified in the COLR. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> B. Part strength groups inserted between the long term steady state 1 on 1 i mit and the transient insertion limit for intervals 7 effective full power days (EFPO)30 EFPD or 14 per 365 EFPO interval.

B.1 Restore part strength CEA groups to within the long term steady state insertion limit. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> (continued)

PALO VERDE UNITS 1,2,3 3.1.8-1 NO. +/-ful., 179 Part Strength CEA Insertion Limits 3.1. 8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and associated Completion Time not met. C.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> SURVEI SR 3.l.8.1 REMENTS SURVEILLANCE Veri part strength CEA group position.

FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1,2.3 3.1.8-2 NO. 179 STE-SDM 3.1. 9 3.1 REACTIVITY CONTROL SYSTEMS 3.1.9 Test Exception (STE) SHUTDOWN MARGIN (SDM) 3.1. 9 During performance of PHYSICS TESTS, the requirements of: LCO 3.1.2. "SHUTDOWN MARGIN (SDM)-Reactor Trip Breakers Closed"; LCO 3.1.6. "Shutdown Control Element Assembly (CEA) Insertion Limi ", and LCO 3.1.7 "Regulating Control Element Assembly (CEA) Insertion Limits" may be suspended for measurement of CEA worth. provided shutdown reactivity equivalent to at least the highest estimated CEA worth (of those CEAs actually withdrawn) is avail ab 1 e for tri p -j nserti on or the reactor is subcri cal by at least the reactivity equivalent of the highest CEA worth. APPLICABILITY:

MODES 2 and 3 during PHYSICS TESTS. ----------

---

NOTE----------Operation in MODE 3 shall be limited to 6 consecutive hours. ACTIONS CONDITION REQUIRED ACTION COMPLETION TH'IE A. Any full strength CEA not fully inserted and less than the required shutdown reactivity available for trip insertion.

OR All full strength CEAs inserted and the reactor subcritical by less than the above required shutdown reactivity equivalent.

A.l Initiate boration to restore required shutdown reactivity.

minutes PALO VERDE UNITS 3.1.9 1 NO. W, 152 STE-SDM 3.1. 9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 9.1 Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition.

2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> SR 3.1. 9.2 Verify each full strength CEA not fully inserted is capable of full insertion when tri pped from at 1 the 50% wi thdrawn positi on. Withi n 7 days prior to reducing SDM requirements to less than the 1 imi ts of LCO 3.1. 2 SR 3.1. 9.3 ---NOTE Only required to be performed in Mode 3. Verify that with all full strength CEAs fully inserted.

the reactor is subcritical within the acceptance criteria.

2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> PALO VERDE UNITS 1.2,3 3.1.9-2 AMENDMENT NO. +/-+/-+,

MODES 1 and 2 3.1.10 REACTIV CONTROL SYSTEMS 3.1.10 Special Test Exceptions ) -MODES 1 and 2 3.1.10 During performance of PHYSICS TESTS, the requirements of: LCD 3.1.4. "Moderator Temperature Coefficient (MTC)": LCD 3.1.5. "Control Element Assembly (CEA) Alignment":

3,1.6, "Shutdown Control Element Assembly (CEA)Insertion Limi ": LCD "Regulating Control Element Assembly (CEA)Insertion Limits": LCO 3.1.8, "Part Strength CEA Insertion Limi ; LCO 3,2 2, "Planar Radial Peaking Factors (Fxy)";LCO 3.2,3. "AZIMUTHAL POWER TILT (Tq)", 3,2.5, "AXIAL SHAPE INDEX (AS!)": and LCO 3.3.3, "Control Element Assembly Calculators (CEACs)" be suspended, provided: THERMAL POWER is restricted to the t power plateau, which shall not exceed 85% RTP: and Shutdown reactivity equivalent to at least the highest estimated CEA worth (of those actually wlthdrawn) is avallable for trip insertion.

APPLICABILITY:

MODES 1 and 2 during PHYSICS TESTS, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, Test power plateau exceeded.

A.l Reduce THERMAL POWER to less than or equal to the t power plateau. 15 minutes B. Required Action and associated Completion me not B.1 Suspend PHYSICS TESTS. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> PALO VERDE UNITS 3.1.10 1 AMENDMENT NO. +/-§g 1'19 STE -MODES 1 and 2 3.l. 10 SURVEILLANCE REQUIREMENTS SR Verify THERMAL POWER equal to or less than the test power plateau. SR Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity additi on.

1 2 PALO VERDE UNITS 3.l.10-2 AMENDMENT NO. ill 158 STE Reactivity Coefficient ting 3.1.11 3.1 REACTIVITY CONTROL SYSTEMS 3.1.11 Special Test Exceptions (STE) Reactivity Coefficient ting LCD 3.1.11 Du ng performance TESTS. the requirements of: 3.1. "Regulating Control Element Assembly (CEA)Insertion Limits": LCD 3.1.8. "Par: Strength Cont Element Assembly (CEA)Insertion Limits;" and LCD 3.4.1. "RCS Pressure.

Temperature and Flow limi (LCD 3.4.1.b. RCS Cold Leg Temperature only) may be suspended.

provided LHR and DNBR do not exceed the limi in the COLR. APPLICABILITY:

MODE 1 with Thermal Power> 20% RTP duri ng PHYSICS ACTIONS COND ON REQUIRED ACTION COMPLETION TIME A. LHR or DNBR outside the 1 imits s fled in the COLR. A.1 Reduce THERMAL POWER to restore LHR and DNBR to within 1 i mits. 15 minutes B. Requlred Action and associated Completlon Time not met. B.1 Suspend PHYSICS TESTS. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.1.11.1 Verify LHR and DNBR do not exceed limits by Continuously performing SR 3.2.1.1 and SR 3.2.4.1. PALO VERDE UNITS 3 1.11-1 NO. , 179 LHR 3.2.1 3.2 POWER DISTRIBUTION 3.2.1 Linear Heat Rate LCO 3.2.1 LHR shall not exceed the limits specified in the APPLICABILITY:

MODE 1 with THERMAL POWER> 20% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core Operating Limit Supervisory System (COLSS) calculated core power exceeds the COLSS c culated core power operating limit based on LHR. A.1 Restore LHR to within limits. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B. LHR not within region B.1 Determine trend in Once per of acceptable LHR. 15 minutes operation when the COLSS is out of service. AND-B.2.1 8.2.2 With an adverse trend, restore LHR to within limit. OR-With no adverse trend, restore LHR to withi n 1 i mits. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> C. Required Action and associated Completion Time not met. C.1 Reduce THERMAL POWER to $ 20% RTP. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1,2,3 3.2.1 1 AMENDMENT NO.

3.2.1 LHR SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1

1. Only applicable when COLSS is out of service. With COLSS in service, LHR is continuously monitored.

2. Not requi red to be performed unti 1 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> after MODE 1 with THERMAL POWER > 20% RTP. Verify LHR, as indicated on any OPERABLE local power density channel, is within its 1 imits. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> SR 3.2.1. 2 Verify the COLSS margin alarm actuates at a THERMAL POWER equal to or less than the core power operating l'imit based on LHR. 31 days PALO VERDE UNITS 1,2,3 3.2.1 2 AMENDMENT NO.

Fxy 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Planar Radi king Factors (Fry) 3.2.2 The measured Planar Radial Peaking Factors shall be equal to or less than the Planar Radial Peaking (F;y) . (These factors Supervisory System (COLSS) and in the Core Protection Calculators (CPCs)). APPLICABILITY:

MODE 1 with THERMAL POWER> 20% RTP. ACTIONS are used in the Core Operati ng Limit CONDITION REQUIRED ACTION COMPLETION TIME A. > A.l.1 Adjust addressable CPC constants to increase the . multiplier applied to planar radial peaking by a factor ;:::

6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> A.1.2 OR Maintain a margin to the COLSS operating 1 imits of [ ( / F;y) -1 . 0 ] x 1uO%. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> A.2 OR Adjust the affected used in the COLSS and CPCs to a value greater than or egual to the measured 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> A.3 Reduce THERMAL POWER to 20% RTP. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1.2.3 AMENDMENT NO.

SURVEILLANCE SR 3.2.2.1 Verify measured obtained using the Incore Detector System is equal to or less than the val ue of used in the COLSS and CPCs.

Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND 31 EFPD thereafter PALO VERDE UNITS 1.2,3 3.2.2-2 AMENDMENT NO.

TCj 3.2.3 3.2 POWER DISTRIBUTION 3.2.3 AZIMUTHAL POWER TI CT qLCO 3.2.3 The measured Tq shall be less than or equal to the allowance used in the Core Protection Calculators (CPCs). APPLICABILITY:

MODE I with THERMAL POWER> 20% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. IVleasured Tl greater than the a lowance used in the CPCs and within the limit in A.I Restore measured T q

• OR -2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> the COLR with COLSS in service OR -Measured T greater than the allowance in the CPCs and 0.03 with COLSS out of service. A.2 Adjust the Tq allowance in the CPCs to greater than or equal to the measured value 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> B. Measured Tq not within the limit ln the COLR with COLSS in service. OR Measured Tq > 0.03 with COLSS out of service. Required Action B.5 must be completed if power reduction commences prior to restoring Tq to within the limit.

B.l Reduce THERMAL POWER to 50% RTP. AND-4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> (continued)

PALO VERDE UNITS 1.2,3 3.2.3-1 AMENDMENT NO.

3.2.3 Tg ACTIONS CONDITION REQUIRED ACTION TIME B. (continued)

B.2 AND B.3 AND-B.4 AND-B.5 Reduce Variable Overpower trip setpoints to ::; 55% RTP. Restore the measured T to 1 ess than the Tq allowance used in the CPCs. Correct the cause for measured Tq not within limlt. Subsequent to power operation>

50% RTP. verify measured Tq is within the limit. 16 hours0.667 days <br />0.0952 weeks <br />0.0219 months <br /> Prior to increasing THERMAL POWER Prior to increasing THERMAL POWER > 50% RTP. Once per hour for 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> OR -Until verified at 95% RTP C. Required Actions and C.1 associated Completion Times not met. Reduce THERMAL POWER to ::; 20%. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1.2.3 3.2.3-2 AMENDMENT NO.

3.2.3 Tg SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.2.3.1 ----------NOTES ---------SURVEILLANCE

1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.

2. Not requi red to be performed unti 1 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> after MODE 1 with THERMAL POWER> 20% RTP. Calculate and verify it is within the 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> 1 i mit. SR 3.2.3.2 Verify COLSS azimuthal tilt alarm is 31 days actuated at a Tq value less than the value used in the CPCs. SR 3.2.3.3 Independently confirm the validity of the 31 EFPD COLSS calculated by use of the incore detectors.

PALO VERDE UNITS 1,2,3 3.2.3-3 AMENDMENT NO.

DNBR 3.2.4 POWER DISTRIBUTION LIMITS 3.2.4 From Nuclea Boiling Ratio (DNBR) LCO The DNBR sha 11 maintained by one of the following methods: Core Operating Limit Supervisory System (COLSS) In Service: Maintaining COLSS calculated core power less than equal to COLSS calculated core power operating limit on DNBR when at least one Control Element Calculator ( ) is OPERABLE in each OPERABLE Core Protection Calculator (CPC)channe 1: or Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit on DNBR decreased by the allowance speci in the COLR when the CEAC requirements of LCD 3.2.4.a.l are not met. COLSS Out of Service: Operating within the region of acceptable operation specified in COLR using any OPERABLE Core Protection Calculator (CPC) channel when at least Control Element Assembly lculator (CEAC) is OPERABLE in OPERABLE CPC channel: or Operating within the region of acceptable operation speci ed in the COLR using any OPERABLE CPC channel (with both CEACs inoperable) when the CEAC requirements of LCD 3.2.4.b.l are not met. APPLICABlL MODE 1 with THERMAL POWER> 20% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETI ON TIME A. calculated core power not within 1 i mit. A.l tore the DNBR to within limit. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (continued)

PALO VERDE UNITS 1.2,3 3 2.4 1 AMENDMENT NO. 179 3,2.4 ACTIONS (continued)

B, CONDITION outs i de the region acceptable operation whenCOLSS is out serVlce, REQUI ACTION B,l Determine trend in DNBR, AND -B.2.1 With an adverse trend, restore DNBR to wi n l'imit, COMPLETION Once per 15 minutes 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> C. Required Action and associated Completion Time not met. B,2,2 C,l Wi no adverse trend. restore DNBR to within limit. Reduce THERMAL POWER to 20% RTP. 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3,2,4,1 1, Only applicable when service, With COLSS in parameter is continuously monitored.

2, Not required to be performed until 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> after MODE 1 with THERMAL POWlR > 20% RTP. Verify DNBR, as indicated on any OPERABLE DNBR channels, is within the li t of the COLR, as applicable.

2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> SR 3.2.4.2 Verify COLSS margin alarm actua a THERMAL POWER level equal to or less than core power operating limit based on , 31 days ce, this PALO VERDE UNI 1,2,3 AMENDMENT NO. -tW, 179 ASI 3.2.5 3.2 POWER DISTRIBUTION 3.2.5 AXIAL SHAPE INDEX LCO 3.2.5 ASI shall be within the limits specified in the APPLICABILITY:

MODE 1 with THERMAL POWER> 20% RTP. ACTIONS CONDITION REQUIRED ACTION ETION TIME A. Core average ASI not withi n 1 i mits. A.1 Restore ASI to within 1 i mits. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> B. Required Action and associated Completion me not met. B.1 Reduce THERMAL POWER to s 20% RTP. 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> SURVEILLANCE SR 3.2.5.1 Not required to be performed until 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> after MODE 1 with THERMAL POWER> 20% RTP. Verify ASI is within limits.

12 PALO VERDE UNITS 1.2.3 3.2.5 1 AMENDMENT NO.

RPS Instrumentation

-Operating 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Protectlve System (RPS) Instrumentation

-Operatlng LCD 3.3.1 r RPS trip and bypass removal channels in Table 3.3.1-1 shall OPERABLE.

Functi on APPLICABILITY:

According to Table 3.3.1 I. ACTIONS Separate Conditlon entry is allowed RPS Function.

REQUIRED ACTION TIME A. One or more Functions with one automatic RPS trip channel inoperable.

A.l AND -A.2 ace channel in bypass or trip. channel to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Prior to i ng MODE 2 following next MODE 5 entry B. One or more with two automa trip channels inoperable ons c RPS B.1 Place one channel in bypass and the other in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (continued)

PALO VERDE UNITS 1.2.3 3.3.1 1 AMENDMENT NO. +/-*&.

3.3.1 RPS Instrumentation Operating ACTIONS (continued)

C. CONDITION One or more Functions with one automatic bypass removal channel inoperable C.1 OR-C.2.1 AND C. 2.2 IRED ACTION Disable bypass channe1 . ace affected automatic trip channel in bypass or trip. Restore bypass removal channel and associ automatic trip channel to OPERABLE status. COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour Prior to entering MODE 2 11 OWl ng next MODE 5 entry D. One or more Functions with two automatic bypass removal channels inoperable.

0.1 OR -0.2 Disable bypass channels Place one affected automatic trip channel in bypass and place the other in trip 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour E. Required Action and associated Completion me not met. E.1 Be in MODE 3 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> nued) PALO VERDE UNITS 1.2.3 3.3.1 2 AMENDMENT NO. +&9, 331 Function.

RPS Instrumentation lng SURVEILLANCE REQUIREMENTS

---

-NOTE to Table 3.3.1-1 to determine which SR shall be performed for RPS 3.3.1.1 SURVEILLANCE Perform a CHANNEL CHECK of each RPS instrument channel. FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.3.1. 2 Not required be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after THERMAL POWER Verify total Reactor Coolant System (RCS)flow rate as indicated by each CPC is less than or equal to the RCS total flow rate. If necessary.

adjust the CPC addressable constant flow coeffici such that each CPC indicated flow is less than or equal to the RCS flow rate. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3 3 1 3 Check the CPC System Log. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> (continued)

UNITS 1.2.3 3.3.1 3 AMENDMENT NO. 179 3.3.1 RPS Instrumentation

-Operating SURVE LLANCE REQUIREMENTS ( nued) SR 3.3.1. 4 SURVEILLANCE

1. Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> a THERMAL POWER 20% RTP. 2. The daily calibratlon may be suspended during PHYSI TESTS. provided the calibration is performed upon reaching each major test power plateau and prlor to proceeding to the next major test power plateau. Perform calibration (heat balance only) and adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC power and CPC nuclear power calculations with the calorimetric.

if the absol difference is 2% when THERMAL POWER is 80% RTP. Between 20% and 80% RTP the maximum difference is O. to 10%. FREQUENCY 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SR 3.3.1. 5 Not required to performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after THERMAL POWER 70% RTP. Verify total ow rate indicated each epe is less than or equal to the flow determined ther using the reactor coolant pump differential pressure instrumentation and the ultrasonic flow meter adjusted pump curves or by calorimetrlc calculations.

31 days (continued)

PALO VERDE UNITS 1.2.3 3.3.1-4 NO. +/-W. 179 3.3.1 RPS Instrumentation

-Ope ng SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.1. 6 SR 3.3.l. 7 SR 3.3.1. 8 SURVEILLANCE ---------NOTE -Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after THERMAL POWER 15% RTP. FREQUENCY Verify linear power subchannel ins of the 31 days excore detectors are consi with the values used to establish the shape annealing matrix elements in CPCs. 1 . The CPC CHANNEL FUNCTIONAL sha 11 include verification that the correct values of addressable cons nts are installed in each OPERABLE CPC. 2. Not required to be performed for logarithmic power level s until 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> after reducing logarithmic power below 1E-4% NRTP. CHANNEL FUNCTIONAL on

-Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION range neutron flux channels the power 92 days 92 days channel. (continued)

PALO VERDE LIN 1.2.3 3.3.1-5 AMENDMENT NO. +/-§#. 179 3.3.1 RPS Instrumentation

-Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1. 9 Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION on each channel, including bypass removal functions.

18 months SR 3.3.1.10 Perform a CHANNEL CPC channel. FUNCTIONAL TEST on each 18 months SR 3.3.1.11 Using the incore detectors, verify the shape annealing matrix elements to be used by the CPCs. Once after each refueling prior to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on automatic bypass removal function, each Once within 92 days prior to each reactor startup SR 3.3.1.13 Neutron detectors are excluded.

Veri fy RPS RESPONSE TIIVIE is wi thi n 1 i mi ts. 18 months on a STAGGERED TEST BASIS PALO VERDE UNITS 1,2,3 3.3.1-6 At-'IENDMENT -l-W, 179 RPS Instrumentation

-Operating 3.3.1 Table 3.3 J-l (page 1 of 3)Reactor Protect we Sys tem 1 nstrumentat 10n MODES QTHtR SPE::I! I EC! SURVE lLLM,CE

[OND]: I JNS REQUIREMfNTS ALLOWABLE VALUE 1. Variable Over Power SR 3.L.. l Celling s 111.0% RTP SR 3.3.1.4 Band s 9.9% RTP SR 3.3.1.6 Iner. Rate s 11.0%/min RTP SR 3.3 1. 7 Deer Rate> 5%/5ee RTP SR 3.3 1 8 SR 3.3 1.9 SR 3.3 1 13 I thmlC Power I eve! -H1 a) SR 3 3.1 sO.OI1% NRTP SR 3 3 1 SR 3.3 1 9 3.3.1.12 SR 3.3.1 13 Pressurlzer Pressure -Hlgh 1.2 SR 3 3 1.1 s 2388 p51a SR 3.3. 7 SR 3 3 1 9 SR 3.3 I 13 4 PresslJri zer Pressure -Low SR 3.3 1 1821 psia SR 3 3 .7 SR 3 3 1 9 SR3.3.1.12 SR 3.3.1.13 Containment Pressure f;lgh 1.2 SR 3 3 '5 3.2 psig SR 3.3 1.7 SR 3 3 1 9 SR 3.3 I 13 Steam Generator

1. 1 Pressure Low 1.2 SR 3 3.1.1 3990 MWt RTP 955 ps i a"* SR 3 3 1.7 SR 3 3 9 SR 3.3 I 13 Steam Generator

1. 2 pressure -Low SR 3 3 1." 3990 MWt RTP 955 ps 1 a"" SR 3 3.1. SR 3.3 1. 9 SR 3.3 1.13 Ca) may be bypasse,j logarlthmlc is > IE 4% NRTP. Bypass shall be automatically removed power lS '5 1[*4% 1 If the as found channel setpolnt lS conservatlYe with respect to the Allm'iable Va:ue but outslde its predetermined as found acceptance crlterld band. then the channel shall be evaluatea to verl that it IS functloni as reqUlred before returnl the to If the foura i setpoint IS conservatlve wlth respect A Ie Value. the channe shall declared inoperab*e to a value that :s wlthin the as-tolerance of the or WI tn I n the as to I erance a setpOl nt that 1 s more conservat lYe than otherw I the channe I sha II be dec! ared I e The UFSAR Tn p nt and the used to determl ne 11 the UFSAR Set pOl nt 2) predeterml as *ound acceptance criterld band. dnd 3) the as I nt erance band are sDeclfled the UFSAR. PALO UNITS 1, 2.3 3.3.1-7 AMENDMENT NO. . 179 3.3.1 RPS Instrumentation

-Operating Table 3 3.1-1 (page 2 of 3)Reactor Protectlve System Instrumentatlon APPLICABLE MODlS OR OTHER SPECIFIED SURVE. I LLANCE FUNC1 ION CONDITIONS REOU I REME.NTS ALLOWABLE VALUE 8. Steam Generator

1. 1 Level -Low 1.2 SR SR SR SR 3 3 1.1 3.3.1. 1 3.3.1. 9 3 3.1.13 2 43 7% 9. Steam Generator

1. 2 Level -Low 1.2 SR SR SR SR 3 3.1. 1 3.3.1 7 3.3 1. 9 3.3 1 13 243.7% 10. Steam Generator

1. l Level -Hlgh 1.2 SR SR SR SR :3 3.1 1 3.3 I 7 3.3.1 9 3.3.1.13 <:: 91 5% 11 Steam Generator

1. 2 Level -Hlgh 1.2 SR SR SR SR 3.3.1. 1 3.3.1. 7 3.3.1.9 3 3.1.13 <:: 91. 5% 12. Reactor Coolant Flow. Generator

1. 1 Low Steam 1.2 SR 3.3.1.1 SR 3.3.1. 7 SR 3 3 1 9 SR331.13 Ramp Floor. Step' 0.115 psid/sec 12.49 psid 17.2 ps I d 13. Reactor Coolant Flow. Generator

1. 2-Low Steam 1.2 SR 3 3 1. 1 SR 3.3.1 7 SR 3.3 1 .9 SR 3.3.1 13 Ramp Floor. Step 0.115 pSld/sec 12 49 pSld 17 2 pSld (contlnued)

PALO VERDE UNITS 1,2,3 3.3.1-8 NO. +/-W, 179 3.3.1 RPS Instrumentation

-Operating 1able 3 3 1*1 3 of 3)Reactor Protect,ve Instrumentation ApJLICABLE OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMEN1S ALLOWABLE VALUE Local Power Denslty 1.2 DepGrture From NJC i i ng 1.2 RatlO (JNBR) SR 3 3.1. 1 <; 21.0 kW/ft SR 3 3 1 2 SR 3 3.1. 3 SR 3.3.1. 4 SR 3.3 1. 5 SR 3.3 1 7 SR 3.3 1 9 SR 3 3 1 10 SR 3 3.1 Jl SR 3 3 1 I? SR33.l.l3 3.3 1 ,?, 1.34 SR 3.3.1. 2 SR 3.3. .3 SR 3 3 1 4 SR 3 3. SR .3 1. 7 SR 3.3. .9 SR 3 3 1 10 3.3.1 11 SR 3.3.1.12 SR3.3.1.13 (b) Trlp may be bypassed when I thmlc power 's < lE4% NRTP Bypass shall be automatica'ly removed wheniogaritrmnc power 1 :::: E*4% NRTP PALO VERDE UNITS 3.3.1-9 AMENDMENT NO. +/-§g. 179 RPS Instrumentation

-Shutdown 3.3.2 3.3 INSTRUMENTATION 3.3.2 Reactor Protective System eRPS) Instrumentation Shutdown LCO Four RPS trip and bypass removal channels for each Function in Table 3.3.2-1 shall be OPERABLE.

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

---

NOTE -------Separate condition entry is allowed for each RPS Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more functions with one automatic RPS trip channel inoperable.

A.l AND-A.2 Place channel in bypass or trip. Restore channel to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Prior to entering MODE 2 following next MODE 5 entry B. One or more functions with two automatic RPS trip channels inoperable.

B.l Place one channel in bypass and place the other in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> PALO VERDE UN 3.3.2-1 AMENDMENT NO. +/-+/-+,

RPS Instrumentation Shutdown 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COIV1PLETION TIME C. One or more functions with one automatic bypass removal channel inoperable.

D. One or more functions with two automatic bypass removal channels inoperable.

C.1 OR C.2.1 AND -C.2.2 0.1 OR-Disable bypass channel. Place affected channel in bypass or trip. Restore bypass removal channel and associated automatic trip channel to OPERABLE status. Disable bypass channels.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour Prior to entering MODE 2 following next MODE 5 entry 1 hOlJr 0.2 Place one affected automatic trip channel bypass and place the other in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> E. Required Action and associated Completion Time not met. E.1 Open all RTCBs. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> PALO VERDE UNITS 1.2.3 3.3.2-2 AMENDMENT NO. ++/-+,

3.3.2 RPS Instrumentation

-Shutdown SURVEILLANCE REQUIREMENTS

---

NOTE Refer to Table 3.3.2-1 to determine which SR shall be performed for each RPS function.

SR 3.3.2.1 SURVEILLANCE Perform a CHANNEL CHECK of each RPS instrument channel. FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.3.2.2 Perform a CHANNEL channel. FUNCTIONAL on each 92 days SR 3.3.2.3 Perform a CHANNEL FUNCTIONAL on automatic bypass removal function.

each Once within 92 days prior to each reactor startup SR 3.3.2.4 Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform a CHANNEL CALIBRATION on each channel, including bypass removal function.

18 months PALO VERDE UNITS 1,2,3 3.3.2 3 AMENDMENT NO.

3.3.2 RPS Instrumentation SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.3.2.5 Neutron detectors are excluded.

Verify RPS RESPONSE TIME is within limits.

18 months on a STAGGERED BASIS PALO VERDE UN 1.2.3 3.3.2-4 AMENDMENT NO.

(a) Witr any Reactor Trip being w1thdrawn.

rent Breakers (RTCBs) closed and any control element assembly capable of (bl se:point be decreased as steam pressure is and nt I rna ntained <:; 200 pS1g tne normal setpolnt steam pressure 1S 1ncreased provided the margin between steam The setpoint shall be automat1cally increased to Cel The setpolnt must be reduced to <:; lE-4% NRTP when less than 4 RCPs are runn1ng Cd) Trip may be when logar1 1S > 1E*4% NRTP. Bypass shal be automat1cally removed (e) 1 If the as found chan"e! setpo1nt IS conservatIve with respect to the A110wable Value but ou:slde 1 ts predeterm" ned as* found acceptance U1 ten a band, the'l the cranne I sha i I be eva I uatec to verl "y that lt lS functlOni requIred before cet:JcT1rg tre charnel to serVice If tre as-fou'ld 1nstrurnent 1S nc:t conservatlVe w1th respect to tre Allowable Value, the [:Iannel UFSAR be reset to a V'at s w,thin the as-left tolerance of the as eft to I er ance of a setpOl nt that 1 more conservat 1 ve than char'le shal I be declared inoperable The UFSAR Trip used to determi ne 1) the UFSAR T r1 p SetpOl nt. 2) the ned as and 3) the as left setpoint tolerance band are spec1f1ed 1n the s'la'l be set:lo'n:

shall W' teli n otherwl RPS Instrumentation Shutdown 3,3,2 Table 3 3 2 I Protective System Instrumentat10n

-Shutdown APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONOlTlONS RFQUIRfMFNTS ALLOWABLE VALVE Logarithmic Power I.evel Hl SR 3 3 2 I SR 3.3 2.2 SR 3.3 2 3 3.3 2 4 3.3 2 5 <:; 0 011% 2. Steam Generator

1. 1 SR 3.3.2.1 3.3.2 2 SR 3.3.2 4 SR 3.3.2. 3990 MWt RTP. %5 PSl 3. Steam Generator

1. 2 3 3.2. SR 3 3, 2 SR 3 3,2,4 SR 3,3,2 5 3990 MWt RTP' PALO VERDE UNITS 1.2.3 3,3.2 5 AMENDMENT NO. +/-e+. 179 CEACs 3.3.3 3.3 INSTRUMENTATION 3.3.3 Control Element Assembly Calculators LCD 3.3.3 Two CEACs shall be OPERABLE in each CPC APPLICABILITY:

MODES 1 and ------------------------------

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

Separate condition entry is allowed for each CPC channel. CONDITION REQLI I RED ACTI ON COMPLETION TIME A. One CEAC inoperable

'j n A.1 Declare the affected one or more CPC CPC channel (s)channels.

inoperable.

OR -A.2.1 Perform SR 3.1.5.1 AND -A.2.2 Restore CEAC to OPERABLE status. Immediately Once per 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> 7 days B. Required Action and B.l Declare the affected associated Completion CPC channel(s)

Time of Condition A inoperable.

not met. DR -OR -Both CEACs inoperable in one or more CPC channels.

Immediately (continued)

PALO VERDE UNITS 1,2,3 3.3.3-1 AMENDMENT NO. 179 3.3.3 CEACs ACTIONS (continued)

CONDI ON REQUIRED ACTION COMPLETION TIME B. (continued)

B.2.1 Veri fy the ,departure from nucleate bOlling ratio requirement of LCO 3.2.4, "Departure from Nucleate Boiling Ratio (DNBR)." is met. AND 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> B.2 2 Verify all fu 11 strength and part strength control element assembly (CEA) groups are lly withdrawn and ma-intained fully withdrawn, except during Surveillance testing pursuant to SR 3.1.5.3 or for control. when CEA group #5 may be inserted to a maximum 127.5 inches withdrawn.

AND B.2.3 Verify the "RSPT/CEAC Inoperable" addressable constant in each affected core protection calculator (CPC) is set indicate that both CEACs are inoperable.

AND 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> (continued)

PALO VERDE UNITS 1,2.3 3.3.3-2 NO. w., 179 3.3.3 CEACs ACTIONS (continued)

CONDITION B.2.4 REQUIRED ACTION Verify the Control Element Drive Mechanism Control System is placed in "STANDBY and maintained in "STANDBY MODE." except during CEA motion permitted by Required Action B.2.2. COMPLETION TIME 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> AND -B.2.5 AND -Perform SR 3.1.5.1. Once per 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> B.2.6 Disable the Reactor Power Cutback System (RPCS) 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> C. Required Action and associated Completion Time of Condition B not met. C.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> PALO VERDE UNITS 1.2.3 3.3.3-3 AMENDMENT NO. +&G.

3.3.3 FREQUENCY 3.3.3.1 Perform a CHANNEL CHECK. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a FUNCTIONAL TEST. 92 days 3.3.3.4 Perform a CHANNEL CALIBRATION.

18 months SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. 18 months PALO VERDE UNITS 1,2,3 AMENDMENT NO , 179 RPS Logic and Trip Initiation 3.3.4 3.3 INSTRUMENTATION 3.3.4 Reactor Protective System (RPS) Logie and Trip Initiation LCO Six channels of RPS Matrix Logic, four channels of RPS Initiation Logic. four channels of reactor trip circuit breakers (RTCBs), and four channels of Manual Trip shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2. MODES 3, 4, and 5. with any RTCBs closed and any control element assemblies capable of being withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Matrix Logic channel inoperable.

OR Three Matrix Logie channels inoperable due to a common power source failure de energi ng three matrix power supplies.

A.l Restore channel to OPERABLE status. 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> PALO VERDE UNITS 1,2,3 AMENOfVlENT NO.

3.3.4 RPS Logic and Trip Initiation ACTIONS (continued)

B. CONDITION

---... ----RTCBs associated with one inoperable channel may be closed for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for the performance of an RPS CHANN FUNCTIONAL TEST. One channel of Manual Trip, RTCB. or Initiation Logic inoperable in MODE 1 or 2. REQUIRED ACTION B.1 Open the affected RTCB. OR -B.2.1 Open the redundant RTCB in the affected Tr-j p Leg. AND-B.2.2 Open the affected RTCB. COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> C. -RTCBs associated with one inoperable channel may be closed for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for the performance of an RPS CHANNEL FUNCTIONAL TEST. One channel of Manual Trip, RTCB, or Initiation Logic inoperable in MODE 3, 4. or 5. C.1 Open the affected RTCB. 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> D. Two channels of RTCBs. Manual Trip or Initiation Logic affecting the same trip leg inoperable.

D.1 Open the affected RTCBs. Immediately (continued)

PALO VERDE UNITS 1,2.3 3.3.4-2 AMENDMENT NO. 117 RPS Logic and Trip Initiation 3.3.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition A, B. or D not met. E.1 AND Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> OR E.2 Open all RTCBs. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> One or more Functions with more than one Manual Trip, Matrix Logic. Initiation Logie. or RTCB channel inoperable for reasons other than Condition A or D. SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel. 92 days SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST. including separate verification of the undervoltage and shunt trips, on each RTCB. 18 months SR 3.3.4.3 Perform a CHANNEL FUNCTIONAL TEST on each RTCB. 31 days PALO VERDE UN 1,2,3 3.3.4-3 AMENDMENT NO.

Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Engineered Safety Features Actuation System (ESFAS) Instrumentation LCO 3.3.5 Four ESFAS trip and bypass removal channels for each Function in Table 3.3.5 1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5-1. ACTIONS -------------

---

NOTE Separate Condition entry is allowed for each ESFAS Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with one automatic ESFAS trip channel inoperable.

A.1 AND -A.2 Place channel in bypass or trip. Restore channel to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Prior to enter-i ng MODE 2 fo 11 owi ng next MODE 5 entry B. One or more Functions with two automatic ESFAS trip channels inoperable.

B.1 Place one channel in bypass and the other -in tr-ip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> PALO VERDE UNITS 1.2.3 3.3.5 1 AMENDMENT NO. +/-+/-+.

ESFAS Instrumentation 3.3.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions with one automatic bypass removal channel inoperable.

C.l OR-C.2.1 AND-C.2.2 Disable bypass channel. Place affected automatic trip channel in bypass or tr-j p. Restore bypass removal channel and associated automatic trip channel to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour Prior to entering MODE 2 following next MODE 5 entry D. One or more Functions with two automatic bypass removal channels inoperable.

0.1 OR -Disable bypass channels.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 0.2 Place one affected automatic trip channel in bypass and place the other in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> E. Required Action and associated Compl on Time not met. E.l AND-Be i n E 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> E.2 Be in MODE 4. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2.3 3.3.5-2 AMENDMENT NO. .

ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS channel. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel. 92 days SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS channel, including bypass removal functions.

18 months SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits. 18 months on a STAGGERED TEST BASIS SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal channel. Once within 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 At-'IENDMENT NO.

3.3.5 Pre-RWT TS Setpoint Change ESFAS Instrumentation Table 3.3.5-1 (page 1 of 1)Engineered Safety Features Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED FUNCTION CONDITIONS ALLOWABLE VALUE 1. Safety Injection Actuation Signal a. Containment Pressure -High 1.2.3 3.2 psig b. Pressurizer Pressure -Low(a) :? 1821 psi a 2. Containment Spray Actuation Signal a. Containment Pressure -High High 1.2.3 8.9 psig 3. Containment Isolation Actuation Signal a. Containment Pressure High 1.2.3 3.2 psig b. Pressurizer Pressure -Low(a) :? 1821 psia 4. Main Steam Isolation Signal(C)

a. Steam Generator

1. 1 Pressure-Low(bl 1.2.3 3990 MWt RTP: 955 psi aId) 3990 MWt RTP: 955 psi a(d)b. Steam Generator

1. 2 Pressure-Low(b)

c. Steam Generator

1. 1 Level-High 91.5% d. Steam Generator

1. 2 Level-High 9l.5% e. Containment Pressure-High 3.2 psig 5. Recirculation Actuation Signal a. Refueling Water Storage Tank Level-Low 1.2.3 6.9 and 7.9% 6. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-l) a. Steam Generator

1. 1 Level-Low 1.2.3 25.3% b. SG Pressure Difference-High 192 psid 7. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2) a. Steam Generator

1. 2 Level-Low 1.2.3 25.3% b. SG Pressure Difference-High 192 psid (a) The setpoint may be decreased to a minimum value of 100 psia. as pressurizer pressure is reduced. provided the margin between pressurizer pressure and the setpoint is maintained 400 psia or 140 psia greater than the saturation pressure of the RCS cold leg when the RCS cold leg temperature is 485°F. Trips may be bypassed when pressurizer pressure is < 400 psia. Bypass shall be automatically removed when pressurizer pressure is 500 psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased. (b) The setpoint may be decreased as steam pressure is reduced. provided the margin between steam pressure and the setpoint is maintained 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure 1S increased. (cl The Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure -Low. Steam Generator High and Containment Pressure -High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed. (d) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band. then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Tri p Setpoi nt. or wi thi n the as 1 eft tolerance of a setpoi nt that is more conservati ve than the UFSAR Trip Set Point; otherwise the channel shall be declared inoperable.

The UFSAR Trip Setpoint and the methodology used to determine

1) the UFSAR Trip Setpoint.

2) the predetermined as found acceptance criteria band. and 3) the as-left setpo1nt tolerance band are specified in the UFSAR. PALO VERDE UNITS 1.2.3 3.3.5-4 AMENDMENT NO. +/-+g. 182 3.3.5 After RWT TS Setpoint ESFAS Instrumentation of :)Table 3.35-1 Engl r'eered Safety Features System InstrumentatIon ALLOWABLE VALUE 1. Safety Injection Actuatlon gnal Contal nllent Pressure 1. 2.3 <; Pressurizer Pressure a) " 1821 2. Containment Spray Actuation Signal Containment Pressure -HIgh HIgh

1. .3 <; 8 9 p51g 3. Con:ainllent Isolatior Actuation Signa i Contalnmert Pressure -Hl 1. 2.3 <; 3 2 ps PressurIzer Pressure al "I8?! a 4. Main Steam !solatlon Ignal(cl a. Steam Generator

1. 1 Pressure*

L 01"\ 1 2. 3990 MWt RTP. " 95:' PS 1 a' b. Steam Generator

1. 2 3990 MWt RTP. " 95S pSla'd. <; 91 5%Steam Generator

1. 1 <; 91. 5%Steam Generator

1. 2 3.2 pS1gContamment Pressure*High

<; 5. Recirculation Actuation Signal Refueli'1g Water Storage Tank Level-Low

.2,3 " 9.15 and <; 9.65%'d: Auxi:l Feedwater Actuatlon Signal SG #1 (AFAS*j Steam

1. 2.3 " 25.3% <; 192 Auxl'lary Feedwater Actuation

':Jna i SG SG Pressure Dl

a. Steam Generator

1. 2 Level-Low

.2.3 b, SG Pressure Dif"erence-H I $ 192 The setpO'int

nay be decreased to a mlnlmum value of lOa pSlo. as zer pressure lS reduced, provlded the margin betwee'l presslJrizer pressure and the setpoi 15 ma1ntalned

<; 400 pSla Jr " 140 psia greater than the saturation of the RCS cold leg the ReS cold leg temperature is ,,485°F. Trips !ray De bypassed :JreSSUrlzer pressure 15 < pSla. Bypass shall be automatlcaiiy removed when pressur1zer presSure IS :::: 500 pSla The seteJoint sha:'1 be autorrat1cally increased to the normal setpomt as pressurizer pressure lS increased. The nt rray be decreased as steam pressure 15 reduced. provided n oetween steall pressure and the setpolnt' mdlntamed

<; 200 p519. The '1t shall be Iy Increased to the normal setpoin! as steam pressure IS lncreased. The Maln Isolatlon Signal (MSIS) Functlon (Steam Generator Pressure -Low, Steam Generator Level* High and Pressure -Hlgh sis) lS not required to be OPERABLE when all assoclated valves lsolated by FunctlOn are ci (d) If the as-found channel setpoH::'

15 conservatlVe with to the Al Ie Value but outside ned as*found crlterla I shall be eva to verl f y that S funct10ning as reqUl returnlng service. If the as* irstrument setpomt is 'lOt conservati ve w'th respect to Value, the channel sna be declared '1 noperab Ie. 2. The l'lStrumert nt shal I be to a value that IS wlthln the as,left tolerance of the UFSAR Tr1p or W1 n the as I tolerance of a nt that's more corservatlve than tne UFSAR T rl othen'il se tne channe 1 sha II be dec 1 lnoperab Ie. The UFSAR Tn p Setpol nt ard the to determl ne ]) Ule UFSAR Tn p nt. 2) the predetorml ned as found acceotance cri and 3) tile as eft setpolnt tolerance band are speclhed in Ule JFSAR PALO VERDE UNI 3.3.5-5 AMENDMENT NO. +/-+g. 182 ESFAS Logic and Manual Trip 3.3.6 INSTRUMENTATION Manua 1 Tr-j p Engineered Safety Features Actuation System (ESFAS) Logic and LCO 3.3.6 Six channels of ESFAS Matrix Logic, four channels of ESFAS Initiation Logic, two channels of Actuation Logic, and four channels of Manual Trip shall be OPERABLE for each Function in Table 3.3.6-1. APPLICABILITY:

According to Table 3.3.6-1. ACTIONS ----------------

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

CONDITION A. One or more Functions with one Matrix Logic channel inoperable.

OR Three Matrix Logic channels are inoperable due to a common power source i 1 ure de-energi ng three matrix power supplies.

A.l REQUIRED ACTION Restore channel to OPERABLE status. COMPLETION TIME 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> B. One or more Functions with one Manual Trip or Initiation Logic channel inoperable.

B.l Restore channel to OPERABLE status. 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> (continued)

PALO VERDE UNITS 1,2,3 AMENDMENT NO. 117 3.3.6 ESFAS Logic and Manual Trip ACTIONS (continued)

C. CONDITION One or more Functions with two Initiation Logic channels or Manual Trip channels affecting the same trip leg inoperable.

C.1 AND-C.2 REQUIRED ACTION Open at least one contact in the tr-j p 1 eg of both ESFAS Actuation Logics. Restore channels to OPERABLE status. COMPLETION TIME Immediately 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> D. One or more Functions with one Actuation Logic channel inoperable.

D.1 -

One channel of Actuation Logic may be bypassed for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for Surveillances.

provided the other channel is OPERABLE.

-

-Restore inoperable channel to OPERABLE status. 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> E. Required Action and associated Completion Time of Conditions for Containment Spray Actuation Signal. Main Steam Isolation Signal or Auxiliary Feedwater Actuation Signal not met. E.1 AND E.2 Be in MODE 3. Be in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2.3 3.3.6 2 AMENDMENT NO.

FAS Logic and Manual Trip 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and associated Compl on Time of Conditions for Safety Injection Actuation gnal, Containment Isolation Actuation Signal, or Recirculation Actuation Signal not met. F.l AND F.2 Be in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SR 3.3.6.1 SURVEILLANCE ---NOTE -Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay. Perform a CHANNEL FUNCTIONAL TEST on each ESFAS logic channel and Manual Trip channel. FREQUENCY 92 days SR 3.3.6.2 -

Relays exempt from testing during operation shall be tested each 18 months. Perform a subgroup relay test of each Actuation Logic channel, which includes the de energization of each subgroup relay and verification of the OPERABILITY of each subgroup relay. 9 months on a STAGGERED TEST BASIS PALO VERDE UNITS 1,2,3 3.3.6-3 AMENDMENT NO.

3.3.6 ESFAS Logic and Manual Trip Table 3.3.6-: (page 1 of 1)Engineered Safety Features Actuation System Logic and Manual Trip Applicability FUNCTION APPLICABLE 1. Safety Injection Actuation Signal a. Matrix Logic b. Initiation c c. Actuation c d. Manual Trip 2. Containment Isolation Actuatlon Signal a. Matrlx Logic b. Initiation Logic c. Actuation Logi d. Manual Trip 3. Recirculation Actuation

a. Matrix Logic b. Initiation Logic c. Actuation Logic d. Manual Trip 4. Containment Spray Actuation Signal a. Matrix b. Initiation Logic c. Actuation Logic d. Manual-rip

5. Main Steam Isolation Signal Ca ) a. Matrix Logic b. Initiation Logic c. Actuation Logic d. Manual Trip 6. Auxiliary Feedwater Actuation SG #1 CAFAS-l) a. Matrix Logic b. Initlatlon Logic c. Actuation Logic d. Manual Tri p 7. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2) a. Matrix Logic b. Initiation Logic c. Actuation Logic d. Manua 1 T ri p l.2.3 1.2.3.4 .2.3.4 1.2.3.4 1.2.3 1.2.3.4 1.2.34 .2.3.4 1. 2.3 1.2.3.4 1.2.3.4 1. 2.3 1.2.3 l.2.3 1.2.3 1. 2.3 1. 2.3 1.2.3 1.2.3 ,2.3 1.2,3 1.2,3 1.2.3 1.2.3 1.2.3 1.2.3 1.2,3 (a) The MSIS Function not required to be OPERABLE when all associated valves isolated the MSIS Function are cl PALO VERDE UNITS 1.2.3 3.3.6-4 AMENDMENT NO. 117 DG LOVS 3.3.7 3.3 INSTRUMENTATION 3.3.7 Diesel Generator COG) -Loss of Voltage Start (LOVS) 3.3.7 Four channels of Loss of Voltage Function and Degraded Voltage Function auto-initiation instrumentation per DG shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. When associated DG is required to be OPERABLE by LCO 3.8.2. "AC Sources -Shutdown." ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One LOVS channel DG inoperable.

per A.1 Place channel in bypass or tri p. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND A.2 Restore channel to OPERABLE status. Prior to entering MODE 2 following next MODE 5 entry PALO VERDE UNITS 1,2,3 3.3.7 AMENDMENT NO.

DG -LOVS 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two LOVS channels per DG inoperable.

B.1 OR -Enter applicable Conditions and Required Actions for the associated DG made inoperable by DG -LOVS instrumentation.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B.2 Place one channel in bypass and the other channel in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> C. More than two LOVS channels per DG inoperable.

C.1 Restore all but two channels to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> D. Required Action and associated Completion Time not met. 0.1 Enter applicable Conditions and Required Actions for the associated DG made inoperable by DG -LOVS instrumentation.

Immediately PALO VERDE UNITS 1.2.3 3.3.7-2 AMENDMENT NO. +/-+/-+.

3.3.7 DG -LOVS SURVEILLANCE REQUIREMENTS SR 3.3.7.1 SURVEILLANCE Perform CHANNEL CHECK. FREQUENCY hours SR 3.3.7.2 Perform CHANNEL FUNCTIONAL 18 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows: a. Degraded Voltage Function 3697 V and :::; 3786 V Time delay: 28.6 seconds and :::; 35 seconds; and b. Loss of Voltage Functi on Time delay: 10.3 seconds and :::; 12.6 seconds at 2929.5 V, and 2.0 seconds and:::; 2.4 seconds at 0 V. 18 months PALO VERDE UNITS 1.2,3 3.3.7 3 AMENDMENT NO. +/-+/-+.

3.3.8 3.3 INSTRUMENTATION 3.3.8 Containment Purge Isolation Actuation Signal (CPIAS) LCO 3.3.8 One CPIAS channel shall be OPERABLE.

MODES 1. 2. 3. and 4. Duri ng CORE AL During movement of irradiated fuel assemblies within containment.

---

NOTE--

---

Only required when the penetration is not isolated by at least one closed automatic valve. closed manual valve. or blind ange. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CPIAS Manual Trip, Actuation Logic. or radiation monitor inoperable in MODES 1. 2. 3. and 4. A.1 Place and maintain containment purge and exhaust valves in closed position.

Immediately B. Required Action and associated Completion Time not met. B.1 Enter applicable Conditions and Required Actions for affected valves of LCO 3.6.3 "Containment Isolation Valves" made inoperable by CPIAS instrumentation.

Immediately PALO VERDE UNITS 1.2.3 AMENDMENT NO.

3.3.8 CPIAS ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. CPIAS Manual Trip, Actuation Logic, or radiation monitor inoperable during CORE AL TERATIONS or movement of irradiated fuel assemblies within conta'j nment. C.1 Place and maintain containment purge and exhaust valves in closed pos iti on. OR C.2.1 Suspend CORE AL TERATIONS.

AND Immediately Immediately C.2.2 Suspend movement of i rradi ated fuel assemblies in conta'j nment. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform a CHANNEL CHECK on required radiation monitor channel. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.3.8.2 Perform a CHANN FUNCTIONAL TEST on each required radiation monitor channel, and Verify the setpo'j nt ::; 2.5 mR/hr. 92 days SR 3.3.8.3 Surveillance of Actuation Logic shall include the verification of the proper operation of each actuation relay. Perform a CHANNEL FUNCTIONAL TEST on required CPIAS Actuation Logic channel. 18 months (continued)

PALO VERDE UN 1. 2,3 3.3.8-2 AMENDMENT NO. 117 3.3.8 CPIAS SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.8.4 Perform a CHANNEL CALIBRATION on requi red radi ion monitor channel. 18 months SR 3.3.8.5 rform CHANNEL FUNCTIONAL TEST on required CPIAS Manual Trip channel. 18 months PALO VERDE UNITS 1.2.3 3.3.8-3 AMENDMENT NO.

CREFAS 3.3.9 3.3 INSTRUMENTATION 3.3.9 Control Room Essential Filtration Actuation Signal (CREFAS) LCO 3.3.9 One CREFAS channel shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, 4. 5. and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CREFAS Manual Trip, Actuation Logic, or radiation monitor inoperable in MODE 1. 2, 3. or 4. A.1 Place one CREFS train in operation.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B. Required Action and associated Completion Time of Condition A not met. B.1 AND B.2 Be in MODE 3. in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1,2,3 3.3.9-1 AMENDMENT NO.

3.3.9 CREFAS ACTIONS (continued)

CONDITION REQUI RED ACTI ON COMPLETION TIME C. CREFAS Manual Trip, Actuation Logic, or radiation monitor inoperable in MODE 5 or 6, or during movement of irradiated fuel assemblies.

C.l OR C.2.1 AND C.2.2 AND C.2.3 SURVEILLANCE Place one CREFS train in operation.

Immediately Suspend movement of irradiated fuel assemblies.

Immediately Suspend positive reactivity additions.

Immediately Suspend CORE ALTERATIONS.

Immediately FREQUENCY SURVEILLANCE SR 3.3.9.1 Perform a CHANNEL CHECK on the required 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> control room radiation monitor channel.

PALO VERDE UNITS 1,2.3 3.3.9-2 AMENDMENT NO.

3.3.9 CREFAS SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.9.2 SURVEILLANCE Perform a CHANNEL FUNCTIONAL on required CREFAS radiation monitor channel. Verify CREFAS high radiation setpoint is $; 2 X 10 5 jJCi Icc. FREQUENCY 92 days SR 3.3.9.3 ---NOTES 1. Surveillance of Actuation Logic shall include the verification of the proper operation of each Actuation relay. 2. Relays associated with plant equipment that cannot be operated during plant operation are required to be tested during each MODE 5 entry exceeding 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> unless tested within the previous 6 months. Perform a CHANNEL FUNCTIONAL TEST on required CREFAS Actuation Logic channel. 18 months SR 3.3.9.4 Perform a CHANNEL CALIBRATION on required CREFAS radiation monitor channel. 18 months SR 3.3.9.5 Perform a CHANNEL FUNCTIONAL on required CREFAS Manual Trip channel. 18 months SR 3.3.9.6 Verify that response time of required CREFAS channel is within limits. 18 months STAGGERED BASIS on a PALO VERDE UNITS 1,2,3 3.3.9-3 AMENDMENT NO.

PAM Instrumentation 3.3.10 3.3 INSTRUMENTATION 3.3.10 Post Accident Monitoring (PAM) Instrumentation LCO The PAM instrumentation for each Function -in Table 3.3.10-1 shall be OPERABLE.

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

---

Separate Condition entry is allowed for each Function.

A. CONDITION One or more Functions with one required channel inoperable.

A.l REQUIRED ACTION Restore required channel to OPERABLE status. COMPLETION TIME 30 days B. Required Action and associated Completion Time of Condition A not met. B.l Initiate action in accordance with Specification 5.6.6. Immediately C. One or more Functions with two required channels inoperable.

C.l Restore one to OPERABLE channel status. 7 days PALO VERDE UNITS 3.3.10 1 AMENDMENT NO. 173 PAM Instrumentation 3.3.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPL ION TIME D. Required Action and associated Completion Time of Condition C not met. 0.1 Enter the Condition referenced in Table 3.3.10-1 for the channel. Immediately E. As required by Required Action 0.1 and referenced in Tab 1 e 3.3.10-1.

E.1 AND-E.2 Be in MODE 3. Be in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> F. As required by Required Action 0.1 and referenced in Table 3.3.10-1.

F.1 Initiate action in accordance with Specification 5.6.6. Immediately PALO VERDE UNITS 1.2,3 3.3.10-2 AMENDMENT NO. ++/-+

PAM Instrumentation 3.3.10 SURVEILLANCE REQUIREMENTS

---

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

These SRs apply to each PAM instrumentation Function in Table 3.3.10 1. SR 3.3.10.1 SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

FREQUENCY 31 days SR 3.3.10.2 -----NOTE Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

18 months PALO VERDE UNITS 1.2.3 3.3.10-3 AMENDMENT NO.

PAM Instrumentation 3.3.10 3 3.10-1 (page 1 of 1)Monitorlng Instrumentation CONDITIONS REFERENCED "ROM FUNCTION REQUIRED CHANNELS REQUIRED ACTION D.1 1. thmic Neutron Flux 2 E 2. Reactor Coolant System Hot Leg Temperature 2 per loop E 3. Reactor Coolant System Cold Temperature 2 per loop E 4. Reactor Coolant System Pressure (wide range) 2 E 5. Reactor Vessel Water Level F 6. Containment Sump Water Level (wide range) 2 E 7. Containment Pressure (wide range) 2 E 8. Containment Isolation Valve Positlon 2 per flow E path CaJCo , 9. Containment Area Radiation (high range) 2 F 10. Pressurizer Level 2 E 11. Steam Generator Water Level (wide range) 2 per steam generator E 12. Condensate Storage Tank Level 2 E 13. Core Exit Temperature Quadrant 1 E 14. Core Exit Temperature Quadrant 2 E 15. Core Exit Temperature

-Quadrant 3 E 16. Core Exit Temperature

-Quadrant 4 2(C) E 17. Steam Generator Pressure 2 per steam generator E 18. Reactor Coolant Subcooling Margin 2 E Monitoring

19. Reactor Coolant System Activity 2 F 20. High Pressure Safety Injection Cold Leg Flow 2 per loop E 21. High Pressure Injection Hot Leg Flow 2 E (a) red for isolation valves whose associ penetration is i OJ at least one closed and vated automatic valve, closed manual ve, blind flange, or valve with flow through the valve secured. (bl Only one position indication channel is required for penetration flow paths with only one installed control room indication channel. (cl A channel consists of two or more core exit (d) A channel is eight sensors in a probe. A channel is OPERABLE if four or more sensors, two or more in the upper four and two or more in the lower four, are OPERABLE.

PALO VERDE UNITS 1.2.3 3.3.10-4 AMENDMENT NO. +/-J+/-.

Remote Shutdown System 3.3.11 3.3 INSTRUMENTATION 3.3.11 Remote Shutdown System LCO 3.3.11 The Remote Shutdown System Instrumentation Functions in Table 3.3.11-1 and each Remote Shutdown System disconnect switch and control circuit shall be OPERABLE.

APPLICABILITY:

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

---

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TItvlE A. One or more required Functions in Table 3.3.11.1 inoperable.

A.l Restore required Functions to OPERABLE status. 30 days B. One or more remote shutdown system disconnect switches or control circuits inoperable.

B.l OR -Restore required switch(s)/circuit(s) to OPERABLE status 30 days B.2 Issue procedure changes that identify alternate disconnect methods or control circui 30 days C. Required Action and C.l Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion Time not met. AND-C.2 Be in MODE 4. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2.3 3.3.11-1 AMENDMENT NO. +/-+/-+.

Remote Shutdown System 3.3.11 SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.3.11.1 Perform CHANNEL CHECK for each required SURVEILLANCE 31 days instrumentation channel that is normally energized.

SR 3.3.11.2 Verify each required control circuit and 18 months transfer switch is capable of performing the intended function.

SR 3.3.11.3 ------------NOTE --------Neutron detectors are excluded from the CHANNEL Perform CHANNEL CALIBRATION for 18 months required instrumentation channel. PALO VERDE UNITS 1.2.3 3.3.11 2 AMENDMENT NO.

Remote Shutdown System 3.3.11 Table 3.3.11-1 (page 1 of 1) Remote Shutdown System instrumentation and Controls FUNCllON/INSTRUMENT REQUIRED NUMBER OF CHANNELS Reacti vi ty Control Log Neutron Reactor Coolant System Pressure Control Pressurlzer Pressure Refuel i ng Water Tank Level c. Charging Line Pressure d Charging Line Flow Decay Heat Removal (via Steam Generators) Reactor Coolant Hot Leg Temperature Reactor Coolant Cold Leg Temperature

c. Steam Generator Pressure d Steam Generator Level Auxil ary Feedwater Flow Decay Heat Removal (via Shutdown Cooling System) Shutdown Cooling Heat Exchanger Temperature Shutdown Cooling Flow Reactor Coolant System Inventory Control Pressurizer Level 2 per loop 1 per 2 per steam 2 per steam 2 per steam 2 2 2 PALO VERDE UNITS 1.2.3 AMENDMENT NO.

Boron Dilution Alarm System (BOAS)3.3.12 3.3 INSTRUMENTATION 3.3.12 Boron Dilution Alarm System (BOAS) LCO 3.3.12 Two channels of BOAS shall be OPERABLE.

APPLICABILITY:

MODES 3. 4. 5 and 6. --------------------NOTE -------Required 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 /> after the neutron flux is within the startup range following a reactor shutdown.

ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. One required channel inoperable.

A.1 Determine the RCS boron concentration.

Immediately AND -At the monitoring Frequency specified in the CORE OPERATING LI M ITS RE PORT B. Two required channels -j noperab 1 e. B.1 Determine the ReS boron concentration by redundant methods. Immediately AND-At the monitoring frequency specifi ed -j n the CORE OPERATING Ur--'IITS REPORT (continued)

PALO VERDE UNITS 1.2,3 3.3.12-1 AMENDMENT NO. 138 Boron Dilution Alarm System (BOAS)3.3. ACTIONS REQUIRED ACTION COMPLETION TIME CONDITION C.1 Suspend all Immediately associated Completion C. Required Action and operations involving Time not met. positive reactivity additions.

PALO VERDE UNITS 1.2.3 3.3.12-2 AMENDMENT NO.

Boron Dilution Alarm System (BDAS)3.3.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.12.1 Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after neutron flux is within the startup range. Perform CHANNEL CHECK. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.3.12.2 -Not required to be performed until 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> after neutron flux is within the startup range. Perform CHANNEL FUNCTIONAL TEST. , 92 days SR 3.3. 12.3 --------------

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

Perform CHANNEL CALIBRATION.

18 months PALO VERDE UNITS 1.2.3 3.3.12-3 AMENDMENT NO.

3.4.1 RCS Pressure, Temperature, and Flow DNB 3.4 REACTOR COOLANT SYSTEM (RCS) RCS Pressure, Temperature.

and Flow Departure from Nucleate Boiling (oNB) Limits LCO RCS DNB parameters for pressurizer pressure, cold leg temperature.

and RCS total flow rate shall be within the limits specified below: a. Pressurizer pressure 2130 psia and 2295 psia; and b. RCS cold leg temperature (Te) shall be within the area of acceptable operation shown in Figure 3.4.1-1; and c. RCS total flow rate 155.8 E6 lbm/hour.

MODE 1 for RCS total flow rate. MODES 1 and 2 for pressurizer pressure, MODE 1 for RCS cold leg temperature (Tc). MODE 2 with Keff 1 for RCS cold leg temperature (Tc). -----------------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. RCS flow rate not with i n 1 i mit . A.l Restore RCS flow to within limit. rate 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> B. Required Action and associated Completion Time of Condition A not met. B.1 Be in MODE 2. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> (continued)

PALO VERDE UNITS 1.2.3 3.4.1-1 AMENDMENT NO. 117 RCS Pressure.

Temperature.

and Flow DNB Limits 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Pressurizer pressure or RCS cold leg temperature not within 1 imits. C.l Restore parameter(s) to within limits. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> D. Required Action and associated Completion Time of Condition C not met. 0.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> SURVEILLANCE SR 3.4.1.1 SURVEILLANCE Verify pressurizer pressure 2295 psia. 2130 psia and FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.1. 2 Verify RCS cold leg temperature within limits as shown in Figure 3.4.1 1. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.1. 3

-Required to be met in MODE 1 with all RCPs running. Verify RCS total flow rate 155.8 E6 lbm/hour.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UN 1. 2.3 3.4.1-2 AMENDMENT NO.

Res Pressure, Temperature, and Flow DNB Limits 3,4,1 Figure 3.4.1 Reactor Coolant Cold Leg Temperature vs. Core Power Level 575 575 u. 0 (0,570)uf a: 570 570 :J (100,564) 565 565 w 560 560o W ..J 555 555 0 8 550 550 545 545 540 540 o 10 20 30 40 50 60 70 80 90 CORE POWER LEVEL., %OF RATED THERMAL POWER (3990 PALO VERDE UNITS 1,2,3 3,4.1 3 AMENDMENT NO. +/-e+.

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for LCD 3.4.2 Each RCS loop temperature (Tco'd) shall be :2:

LITY: MODE 1. MODE 2 with Keff :2: 1.0. ACTIONS COND ION REQUIRED ACTION COMPL ON TIME A. Tcold in one or more RCS loops not within 1 imit. A.1 in MODE 3. 30 minutes SURVEILLANCE SR 3.4.2.1 Verify RCS in each loop :2: 545°F.

---

Only required if any RCS loop < 550°F. 30 minutes AND Once within 30 minutes prior to reaching criti ca 1 ity PALO VERDE UNITS 1.2.3 AMENDMENT NO.

RCS PIT Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (PIT) Limits LCO 3.4.3 RCS pressure.

RCS temperature.

and RCS heatup and cool down rates shall be maintained within the limits specified in the PTLR. APPLICABILITY:

At all times: except when reactor vessel head is fully detensioned such that the RCS cannot be pressurized. CONDITION REQU IRED ACTI ON COMPLETION ME A. -------NOTE Required Action A.2 shall be completed whenever this Condition is entered. -----Requirements of LCO not met in MODE 1. 2, 3, or 4. A.l AND-A.2 Restore parameter(s) to within limits. Determine RCS is acceptable for continued operation.

30 minutes 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Required Action and associated Completion Time Condition A not met. B.l AND-B.2 Be in MODE 3. Be in MODE 5 with RCS pressure < 500 pSia. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1,2.3 3.4.3-1 AtvlENDlVlENT NO. ,

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RCS PIT Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -------NOTE--

C.1 Initiate action to Required Action C.2 restore parameter(s) shall be completed to within limits. whenever this Condition is entered. AND -C 2 Determine RCS is Prior to Requirements of LCO acceptable for entering MODE 4 not met any time in continued operation.

other than MODE 1. 2. 3. or 4. SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.3.1 Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing. Verify RCS pressure.

RCS temperature.

and RCS heatup and cool down rates within limits specified in the PTLR. 30 minutes PALO VERDE UNITS 1.2.3 3.4.3-2 Amendment No. W.

RCS Loops -MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops -MODES 1 and LCD 3.4.4 Two RCS loops shall be OPERABLE and in APPLICABILITY:

MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION COMPLETION ME A. Requirements of LCD not met. A.l Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2,3 3.4.4-1 AMENDMENT NO.

RCS Loops -MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops -MODE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE and one RCS loop shall be in operation.

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All reactor coolant pumps may be de-energized 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 10°F below saturation temperature.

APPLICABILITY:

MODE 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required RCS loop inoperable.

A.l Restore required RCS loop to OPERABLE status. hours B. Required Action and aSSOCiated Completion me of Condition A not met. B.l Be in MODE 4. hours PALO VERDE UNITS 1,2,3 3.4.5-1 AMENDMENT NO.

RCS Loops -MODE 3 3.4.5 ACTIONS No RCS loop OPERABLE.

OR No RCS loop in operation.

C.1 AND C.2 SURVEILLANCE REQUIRED Suspend all operations involving a reduction of RCS boron concentration.

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

COIV1PLETION TItJlE Immediately Immediately SR 3.4.5.1 SURVEILLANCE Verify required RCS loop is in operation.

FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.5.2 Verify secondary side water level steam generator 25%. in each 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.5.3 Verify correct breaker alignment and indicated power available to the required pump that is not in operation.

7 days PALO VERDE UNITS 1,2,3 AMENDMENT NO.

RCS Loops -MODE 4 3.4.6 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops -MODE 4 3.4.6 Two loops or trains consi ng of any combination of RCS loops and shutdown cooling (SOC) trains shall be OPERABLE and at lone loop or train shall be in operation.

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NOTES--------All reactor coolant pumps (RCPs) and SOC pumps may be de-energized 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: operations are permitted that would cause reduction of the RCS boron concentration; and Core outlet temperature is mainta'ined at 110°F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature less than or equal to the LTOP enable temperature specified in the PTLR unless the secondary side water temperature in each Steam Generator (SG) is < 100°F above each the RCS cold leg temperatures. No more than 2 RCPs may be in operation with RCS cold leg temperature 200°F. No more than 3 RCPs may be in operation with RCS cold leg temperature>

200°F but 500°F. APPLICABILITY:

MODE 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required RCS loop inoperable.

AND Two SOC trains inoperable.

A.l Initiate action to restore a second loop or train to OPERABLE status. Immediately (continued)

PALO VERDE UNITS 1.2,3 3.4.6 1 AMENDMENT NO. , 178 RCS Loops -MODE 4 3.4.6 ACTIONS (continued)

CONDITION B. One required SDC train inoperable.

AND -Two required RCS loops inoperable.

B.1 REQUIRED ACTION Be in MODE 5. COMPLETION 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. No RCS loop or SDC train OPERABLE.

OR-C.1 Suspend all operations involving reduction of RCS boron concentration.

Immediately No RCS loop or SDC train in operation.

AND-C.2 I ni ate action to restore one loop or train to OPERABLE status and operation.

Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RCS loop or SDC train is in operation.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.6.2 Verify secondary side water level in required SG(s) is 25%. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UN 1.2,3 3.4.6-2 AMENDMENT NO.

3.4.6 RCS Loops -MODE SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.6.3 Verify correct breaker alignment and 7 days indicated power available to the required pump that is not in operation.

PALO VERDE UNITS 1.2.3 3.4.6 3 AMENDMENT NO.

RCS Loops MODE 5. Loops lled 3.4.7 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops MODE 5. Loops lled LCO One Shutdown Cooling (SOC) train shall be OPERABLE and in operation.

and either: One addi onal SOC train shall be OPERABLE; or The secondary side water level of each Steam Generator (SG) shall be 25%. -------------The SOC pump of the train in operation may be de-energized 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 RCS boron concentration; and Core outlet temperature is maintained at least 10°F below saturation temperature. One required SOC train may be inoperable for up to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for survei 11 ance test-j ng provi ded that the other SOC train is OPERABLE and in operation. No Reactor Coolant Pump (RCP) shall be started with one or more of the RCS cold leg temperatures less than or equal to the LTOP enable temperature specified in the PTLR unless the secondary side water temperature in each SG is < 100°F above each of the RCS cold leg temperatures. No more than 2 RCPs may be in operation with RCS cold leg temperature

$ 200°F. No more than 3 RCPs may be in operation with RCS cold leg temperature>

200°F but $ 500°F. All SOC trains may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

MODE 5 with RCS loops filled. PALO VERDE UNITS 3.4.7 1 AMENDMENT NO. ,

RCS Loops MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SOC train inoperable.

AND -A.1 Initiate action to restore a second SOC train to OPERABLE status. Immediately Any SG with secondary side water level not with i n 1 i mit . OR A.2 Ini ate action to restore SG secondary side water levels to withi n 1 i mits. Immediately B. Required SOC train inoperable.

OR-No SOC train in operation.

B.1 AND-B.2 Suspend all operations involving reduction in RCS boron concentration.

Initiate action to restore one SOC train to OPERABLE status and operation.

Immediately Immediately PALO VERDE UNITS 1.2.3 3.4.7 2 AMENDMENT NO.

3.4.7 RCS Loops -MODE 5, Loops lled SURVEILLANCE REQUIREMENTS SR 3.4.7.1 SURVEILLANCE Verify one SOC train is in operation.

FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.7.2 Veri fy requ-j red SG secondary si de water level is 25%. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.7.3 Verify correct breaker alignment and indicated power available to the required SOC pump that is not in operation.

7 days PALO VERDE UNITS 1,2,3 3.4.7-3 AMENDMENT NO.

RCS Loops -MODE 5, Loops Not Filled 3.4.8 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS -MODE 5. Loops Not Filled LCO Two Shutdown Cooling (SOC) trains shall be OPERABLE and one SOC train shall be in operation.

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NOTES---------All SOC pumps may be de-energized for s 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: The core outlet temperature is maintained>

10°F below saturation temperature; No operations are permitted that would cause a reduction of the RCS boron concentration; and No draining operations to further reduce the RCS water volume are permitted. One SOC train may be inoperable for s 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for surveillance testing provided the other SOC train is OPERABLE and in operation.

MODE 5 with RCS loops not filled. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SOC train inoperable.

A.1 Initiate action to restore SOC train to OPERABLE status. Immediately PALO VERDE UN 1.2.3 AMENDMENT NO.

RCS Loops -MODE 5, Loops Not Fi 11 ed 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required SOC trains inoperable.

OR No SOC tra-j n in operation.

B.l AND B.2 Suspend all operations involving reduction of RCS boron concentration.

Initiate action restore one SOC train to OPERABLE status and operation.

Immediately Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SDC train is in operation.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.8.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation.

7 days PALO VERDE UNITS 1,2,3 3.4.8 2 AMENDMENT NO.

Pressurizer 3.4.9 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer 3.4.9 The pressurizer shall be OPERABLE with: Pressurizer water level 27% and 56%; and Two groups of pressurizer heaters OPERABLE with the capacity of each group 125 kW. APPLICABILITY:

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

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

The pressurizer water level limit does not apply during: THERMAL POWER ramp> 5% RTP per minute; or THERMAL POWER step> 10% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION A. Pressurizer water level not within limit . A.l AND-A.2 Be in MODE 3 with reactor trip breakers open. Be in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> B. One required group of pressurizer heaters inoperable.

B.l Restore required group of pressurizer heaters to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> PALO VERDE UNITS 3.4.9-1 NO. ill, 164 Pressurizer 3.4.9 ACTIONS (cont*j nued) CONDITION REQUIRED ACTION COMPLETION ME C. Required Action and associated Completion me of Condition B not met. C.l AND C.2 Be in MODE 3. Be in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is 27% and 56% 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters 125 kW. 92 days PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO.

Pressurizer Safety Valves-MODES

1. 2. and 3 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves Modes 1. 2 and 3 LCO Four pressurizer safety valves shall be OPERABLE with lift settings 2450.25 psia and s 2549.25 psia.

MODES I, 2. and 3. ----------NOTE---------

The lift settings are not required to be within 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 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> following entry into MODE 3 provided a preliminary cold setting was made prior to heatup. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety valve inoperable.

A.l Restore valve to OPERABLE status. 15 minutes B. Required Action and associated Completion Time not met. OR-Two or more pressurizer safety valves inoperable.

B.1 AND-B.2 Be in MODE 3. Be in MODE 4 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2,3 AMENDMENT NO.

Pressurizer Safety Valves-MODES

1. 2. and 3 3.4.10 SURVEILLANCE SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in accordance with the Inservice Testing Program. Following testing. lift settings shall be within +/- 1%.

In accordance with the Inservice Testing Program PALO VERDE UNITS 1,2.3 3.4.10-2 AMENDMENT NO.

Pressurizer Safety Valves-MODE 4 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Safety Valves-MODE 4 LCO 3.4.11 One pressurizer safety valve shall be OPERABLE with setting 2450.25 psia and 2549.25 psia. a lift APPL ICABILITY:

MODE 4 with all RCS cold leg temperatures greater than the LTOP enable temperature specified in the PTLR.

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NOTE The lift settings are not required to be within 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 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> following entry into MODE 3 provided a preliminary cold setting was made prior to heatup. ACTIONS CONDITION . All pressurizer safety valves inoperable.

REQUI RED ACTI ON A.l Be in MODE 4 with one Shutdown Cooling System suction line relief valve in service. AND A.2 Perform SR 3.4.11.2 and SR 3.4.11.3 for the required Shutdown Cooling System suction line re 1 i val ve to comply with Action A.I. AND A.3 Be in MODE 4 with any RCS cold leg temperature less than or equal to the LTOP enable temperature specified in the PTLR. COMPLETION Immediately Irnmedi ately 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> PALO VERDE UNITS 3.4.11-1 AMENDMENT NO. +/-+/-+.

Pressurizer Safety 'Valves-MODE 4 3.4.1l SURVEILLANCE REQUIREMENTS SR 3.4 .1l.1 SURVEILLANCE Verify the required pressurizer safety valve is OPERABLE in accordance with the Inservice Testing Program. Following testing, li settings shall be within +/- 1%. FREQUENCY In accordance with the Inservice Testing Program SR SR 3.4.1l. 2 3.4.1l.3 -NOTE Only required to be performed when a Shutdown Cooling System suction line reli valve is being used for overpressure protection.

-Verify the required Shutdown Cooling System suction line relief valve is aligned to provide overpressure protection for the RCS. Verify the required Shutdown Cooling System suction line relief valve is OPERABLE with the required setpoint.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> for unlocked, not sealed. or otherwise not secured open pathway vent valve(s) AND 31 days for locked, sealed,' or otherwise secured open pathway vent valve(s) In accordance with the Inservice Testing Program PALO VERDE UNITS 1. 2,3 3.4.11-2 AMENDMENT NO.

Pressurizer Vents 3.4.12 3.4 REACTOR COOLANT SYSTEM 3.4. Pressurizer LCD 3.4.12 Four pressuri zer vent paths shall be APPLICABILITY:

MODES 1. 2. and 3. MODE 4 with RCS pressure 385 psia. ACTIONS CONDITION REQUIRED ACTION COMPL ON TIME A. Two or three required pressurizer vent paths inoperable.

A.1 Restore required pressurizer vent paths to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. All pressurizer vent paths inoperable.

B.1 Restore one pressurizer vent path to OPERABLE status. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> C. Required Action and associated Completion Time of Condition A. or B not met. C.1 AND-C.2 Be in MODE 3. Be in MODE 4 with RCS pressure < 385 psia. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.12.1 Perform a complete cycle of each Pressurizer Vent Valve. 18 months SR 3.4.12.2 Verify flow through each pressurizer vent path. 18 months PALO VERDE UNITS 1.2.3 3.4.12 1 NO. 117 LTOP System 3.4.13 REACTOR COOLANT SYSTEM (RCS) 3.4.13 Low Temperature Overpressure Protection (LTOP) System 3.4.13 An LTOP System shall be OPERABLE consisting of: Two OPERABLE Shutdown Cooling System suction line relief valves with li ngs $ 467 psig aligned to provide overpressure protection for the RCS; or The RCS depressuri zed and an RCS vent of 16 square inches. -------------------

NOTE--------------No RCP shall be started unless the secondary side water temperature in each steam generator (SG) is $ 100°F above each of the RCS cold 1 temperatures.

APPLICABILITY:

MODE 4 when any RCS cold leg temperature is less than or equal to the LTOP enable temperature specified in the PTLR. 5. MODE 6 when the reactor vessel head is on. --------------

NOTE-------

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3.0.4.b is not applicable when entering MODE 4. ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. One required Shutdown Cooling System suction line relief valve inoperable in MODE 4. A.l Restore required Shutdown Cooling System suction line relief valve to OPERABLE status. 7 days PALO VERDE UNITS 3.4.13 1 AMENDMENT NO. +/-ee.

LTOP System 3.4.13 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPL ION TIME B. One required Shutdown Cooling System suction line relief valve inoperable in MODE 5 or 6. B.l Restore required Shutdown Cooling System suction line relief valve to OPERABLE status. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. Two required Shutdown Cooling System suction line relief valves inoperable.

OR-Required Action and associated Completion Time of Condition A. or B not met. C.l Depressurize RCS and establish RCS vent of 16 square inches. 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> PALO VERDE UNITS 1.2.3 3.4.13-2 AMENDMENT NO.

LTOP System 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 Verify RCS Vent 16 square inches is open. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> for unlocked.

not sealed. or otherwise not secured open vent pathway(s)

AND 31 days for locked. sealed. or otherwise secured open vent pathway(s)

SR 3.4.13.2 Verify each Shutdown Cooling System suction line relief valve is aligned to provide overpressure protection for the RCS. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> for unlocked.

not sealed. or otherwise not secured open pathway vent valve(s) AND 31 days for locked. sealed. or otherwise secured open pathway vent valve(s).

SR 3.4.13.3 Verify each Shutdown Cooling System suction line relief valve is OPERABLE with the required setpoint.

In accordance with the Inservice ng Program. PALO VERDE UNITS 1.2.3 3.4.13 3 AMENDMENT NO.

RCS Operational LEAKAGE 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Operational LEAKAGE LCO 3.4.14 RCS operational LEAKAGE shall be limited to: a. No pressure boundary LEAKAGE: b. 1 gpm uni dentifi ed LEAKAGE: c. 10 gpm identi ed LEAKAGE; and d. 150 gallons per day primary to secondary LEAKAGE through anyone steam generator (SG). APPLICABILITY:

MODES 1. 2, 3. and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION ME A. RCS operational LEAKAGE not withi n limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE. A.1 Reduce LEAKAGE to within limi 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> B. Required Action and associated Completion Time of Condition A not met. B.1 AND-Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> OR-Pressure boundary LEAKAGE exists. OR-Primary to secondary LEAKAGE not within 1 imi t. B.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1.2.3 3.4.14-1 AMENDMENT NO. 161 RCS Operational LEAKAGE 3.4.14 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.14.1 NOTES I. Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after establishment of steady state operation.

2. Not applicable to primary to secondary LEAKAGE Perform RCS water inventory balance. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> SR 3.4.14.2 Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after establishment of steady state operation.

Verify primary to secondary LEAKAGE is s 150 gallons per day through anyone SG. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> PALO VERDE UNITS 1.2.3 3.4.14-2 AMENDMENT NO. +/-+/-7.

RCS PIV Leakage 3.4.15 REACTOR COOLANT SYSTEM 3.4.15 RCS Pressure Isolation Valve (PIV) LCO 3.4.15 Leakage from each RCS PIV shall be within APPLICABILITY:

MODES 1. 2. and 3. MODE 4. except valves in the shutdown cooling (SOC) flow path when in, or during the transition to or from. the SOC mode of operation.

ACTIONS ----------------------------NOTES ---------------------Separate Condition entry is allowed for each flow path. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths with leakage from one or more RCS PIVs not withi n 1 i mit Each valve used to satisfy Required Action A.1 and required Action A.2 must have been verified to meet SR 3.4. . 1 and be on the RCS pressure boundary.

A.1 Isolate the high pressure portion of AND A.2 the affected system from the low pressure portion by use of one closed manual. deactivated automatic.

or check valve. Restore RCS PIV to withi n 1 imits 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> (continued)

PALO VERDE UNITS 1.2,3 AMENDMENT NO. 117 RCS PIV Leakage 3.4.15 ACTIONS (Continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and associated Completion me for Condition A not met. B.1 AND B.2 Be in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SR 3.4.15.1 ----------

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NOTES

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Not requi red to be performed in MODES 3 and 4. Not required to be performed on the RCS PIVs located in the SOC flow pathin the shutdown cooling mode of operation.

3. RCS PIVs actuated duri ng the performance of this Surveillance are not required to be tested more than if a repetitive testing loop cannot be avoided. Verify leakage from each RCS PIV is equivalent to S 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure 2230 psia and S 2270 psia.

18 months AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months, except for SOC PIVs AND (continued)

PALO VERDE UNITS 1,2.3 3.4. AMENDMENT RCS PIV Leakage 3.4.15 SURVEILLANCE REQUIREMENTS (Continued)

SURVEILLANCE FREQUENCY SR 3.4.15.1 (continued)

Withi n 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> following valve actuation due to automatic or manual action or flow through the valve, except for SOC PIVs. SR 3.4.15.2 Verify SOC System open permissive interlock prevents the valves from being opened with a simulated or actual RCS pressure signal 410 psia. 18 months PALO VERDE UNITS 1.2.3 3.4.15 3 AMENDMENT NO.

RCS Leakage Detection Instrumentation 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS kage Detection Instrumentation LCO Both of the following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump monitor; and b. One containment atmosphere radioactivity monitor (gaseous and particulate).

1. 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION ME A. Required containment sump monitor inoperable.

A.l AND A.2 Perform SR 3.4.14.1.

Restore containment sump monitor to OPERABLE status. Once per 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> 30 days (cont'i PALO VERDE UN 1. 3.4.16-1 AMENDMENT NO. ,

RCS Leakage Detection Instrumentation 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION i COMPLETION TIME B. Required containment atmosphere radioactivity monitor inoperable.

B .1.1 OR -B.1.2 AND Analyze grab samples of the containment atmosphere.

Perform SR 3.4.14.1.

Once per 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> Once per 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. Required Action and associated Completion Time not met. B.2 C.1 AND-Restore required containment atmosphere radioactivity monitor to OPERABLE status. Be in MODE 3. 30 days 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> C.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> D. All required monitors inoperable.

D.l Enter LCO 3.0.3 Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.16.1 Perform CHANNEL CHECK of the required containment atmosphere radioactivity monitor. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.16.2 Perform CHANNEL FUNCTIONAL TEST of the required containment atmosphere radioactivity monitor. 92 days PALO VERDE UNITS 1.2.3 3.4.16-2 AMENDMENT NO. +/-+/-+.

RCS Leakage Detection Instrumentation 3.4.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.3 Perform CHANN CALIBRATION of the required containment sump monitor. months SR 3.4.16.4 Perform CHANNEL CALIBRATION of the required containment atmosphere radioactivity monitor. 18 months PALO VERDE UNITS 1.2.3 3.4.16-3 AMENDMENT NO.

RCS Speci c Activity 3.4.17 REACTOR COOLANT (RCS) 3.4.17 RCS Specific Activity LCO The specific activity of the reactor coolant shall be within 1 i mits.

MODES 1 and 2. MODE 3 with RCS cold leg temperature (T w,d ) 500°F. ACTIONS CONDITION REQUIRED ACTION I COMPLETION TIME A. DOSE EQUIVALENT I 131 -------> 1.0 /JCi/gm. LCO 3.0.4.c is applicable. Veri fy DOSE Once per EQUIVALENT 1-131 within 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> the acceptable region of gure 3.4. -1. AND Restore DOSE EQUIVALENT 1-131 to within 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> 1 i mit.

PALO VERDE UNITS 3.4.17 1 AMENDMENT NO. +/-+/-+,

RCS Specific Activity 3.4.17 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and associated Compl on Time of Condition A not met. OR -DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.17-l.

B.l Be in MODE 3 with d < 500°F. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> C. Gross specific activity the reactor coolant not wi th i n 1 i mit . C.l Perform SR 3.4.17.2.

AND 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> C.2 Be in MODE 3 with T co1d < 500°F. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify reactor coolant gross specific 7 days acti vity 1001 E /.lCi Igm.

PALO VERDE UNITS 1,2.3 3.4.17 2 AMENDMENT NO.

RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT I-131 specifi cacti vity ::; 1. 0 pCi Igm. -NOTE Only required to be performed in MODE 1. 14 days AND Between 2 and 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> after 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 SR 3.4.17.3 -Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours2 days <br />0.286 weeks <br />0.0658 months <br />. Determi ne E from a samp 1 e taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours2 days <br />0.286 weeks <br />0.0658 months <br />. 184 days PALO VERDE UNITS 1,2.3 3.4.17-3 AMENDMENT NO.

RCS Specific Activity 3.4.17 E EnU :::1.::E :::; U C U II.U W D. U') Z j o o u a: o U C w a: .,.. ('I).,.. IZ W:) a w w U') j I I I . , . I

• I I I * , , , ,.. 1 I ) I f ,I I I I I -I I

• I , -I I I , I -I

• j * , I I -I I I I' I I '\' I' . I t * '.1 I I I I ", , I .I , 'It , . ., . '\' . I .\, I

• I I .I I I '\. ; I I I\. .* I I , .., . , I , , I , o Q 20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER Figure 3.4.17 1 (page 1 of Reactor Coolant DOSE EQUIVALENT 1-131 Specific Activity Versus Percent of RATED THERMAL POWER With Reactor Specific Activity>

1.0 DOSE EQUIVALENT PALO VERDE UNITS 1,2,3 3.4.17-4 Amendment No. 117 SG Tube Integrity 3.4.18 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.18 Steam Generator (SG) Tube Integrity LCO 3.4.18 SG tube integrity shall be maintained.

AND All SG tubes satisfying the tube repai r criteria shall be plugged in accordance w ith the Steam Generator Program. APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS ---NOTE -Separate Condition entry is allowed for each SG CONDITION REQU I RED ACTI ON COMPL ETI ON TI ME A. One or more SG tubes A.1 Verify tube integrity 7 days satisfying the tube of the affected repair criteria and tube(s) is maintained not plugged in until the next accordance with the refueling outage or Steam Generator SG tube inspection.

Program. AND-A.2 Plug the affected tube(s) in accordance with the Steam Generator Program. Prior to entering MODE 4 following the next refueling outage or SG tube inspection.

B. Required Action and associated Completion Time of Condition A not met. B.1 Be in MODE 3. AND-6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> OR-SG tube integrity not maintained.

B.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1,2,3 3.4.18-1 AMENDMENT NO.

SG Tube Integrity 3.4.18 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.18.1 Verify SG tube integrity in accordance with the Steam Generator Program. In accordance with the Steam Generator Program. SR 3.4.18.2 Verify that each inspected SG tube that satisfies the tube repair criteria is plugged in accordance with the Steam Generator Program. Prior to entering MODE 4 fo 11 owi ng a SG tube inspection.

PALO VERDE UNITS 1.2.3 3.4.18-2 AMENDMENT NO.

SITs-Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Safety Injection Tanks (SITs) -Operating LCD 3.5.1 Four SITs shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2. MODES 3 and 4 with pressurizer pressure 1837 pSia. ACTIONS CONDITION A. One SIT inoperable due to boron concentration not within limits. OR -One S inoperable due to inability to verify level or pressure.

A.1 REQUIRED ACTION Restore SIT to OPERABLE status. COMPLETION TIME 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. One SIT inoperable for reasons other than Condition A. B.1 Restore SIT to OPERABLE status. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. Required Action and associated Completion me of Condition A or B not met. C.l AND-Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> C.2 Reduce pressurizer pressure to < 1837 psia. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> D. Two or more SITs inoperable.

0.1 Enter LCD 3.0.3. Immediately PALO VERDE UN 1.2.3 3.5.1-1 AMENDMENT NO. +/-+/-+.

3.5.1 SITs-Operating SURVEILLANCE REQUIREMENTS FREQUENCY SURVEILLANCE SR 3.5 .l.1 Verify each S isolation valve is fully 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> open. SR SR SR 3.5.1.2 3.5.1. 3 3.5.1.4 Verify borated water volume in each SIT is 28% narrow range and 72% narrow range. Verify nitrogen cover pressure in each S is 600 psig and 625 psig. Verify boron concentration in each SIT is 2300 ppm and 4400 ppm. SR 3.5.1. 5 Verify power is removed from each SIT isolation valve operator.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> 31 days AND -NOTE Only required to be performed for affected SIT Once within 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br />. whenever a SIT is drained to maintain the contained borated water level within the limi of SR 3.5.1. 2. 31 days PALO VERDE UNITS 1.2.3 3.5.1-2 AMENDMENT NO.

SITs-Shutdown 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 Safety Injection Tanks (SITs)-Shutdown LCD 3.5.2 Four SITs shall be OPERABLE with a borated water volume > 39% wide range indication and < 83% wide range indication; OR Three SITS shall be OPERABLE with a borated water volume > 60% wide range indication and < 83% wide range indication.

APPLICABILITY:

MODES 3 and 4 with pressurizer pressure < 1837 psia. ACTIONS A. OR-B. CONDITION One required SIT inoperable due to boron concentration not within limits. One requi red SIT inoperable due to inability to verify level or pressure.

One requi red SIT inoperable for reasons other than Condition A. A.1 B.1 REQUI RED ACTI ON Restore required SIT to OPERABLE status. Restore required SIT to OPERABLE status. COMPLETION TIME 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. OR -D. Inoperability of the required SIT was discovered but not restored while in ITS 3.5.l. "SITs-Operating" Required Action and associated Completion Time of Condition A or B not met. Two or more required SITs inoperable.

C.1 D.1 Be in MODE 5. Enter LCD 3.0.3. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> Immediately PALO VERDE UNITS 1.2.3 3.5.2 1 NO. W. 118 3.5.2 SITs Shutdown SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is fully open when pressurizer pressure is ;::: 430 psia. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.5.2.2 Verify borated water volume in each requi red SIT is: a. For four OPERABLE SITs. > 39% wide range indication and < 83% wide range indication.

OR b. For three OPERABLE SITs. > 60% wide range indication and < 83% wide range indication.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.5.2.3 Verify nitrogen cover pressure in each required SIT is ;::: 260 psig and $ 625 psig. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.5.2.4 Verify boron concentration in each required SIT is ;::: 2300 ppm and $ 4400 ppm. 31 days AND Only required to be performed for affected SIT Once withi n 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br />. whenever a requi red SIT is drained to maintain the contained borated water 1 evel withi n the 1 i mits of SR 3.5.2.2. (continued)

PALO VERDE UNITS 1.2,3 3.5. AMENDMENT NO. 117 3.5.2 SITs SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify power is removed from each required SIT isolation valve operator when pressurizer pressure is 2 1500 psia. 31 days PALO VERDE UNITS 1. 2.3 3.5.2-3 AMENDMENT NO.

ECCS -Operating 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS LCD 3.5.3 Two ECCS trains shall be APPLICABILITY:

MODES 1 and 2. MODE 3 with pressurizer pressure 1837 pSia or with RCS Te 485°F. ACTIONS A. CONDITION One LPSI subsystem inoperable.

A.l REQUIRED ACTION Restore subsystem to OPERABLE status. COMPL 7 days ON TIME B. One or more trains inoperable for reasons other than Condition A. AND-At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

B.l Restore train(s) to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> C. Required Action and associated Completion Time not met. C.l AND-C.2 AND-C.3 Be i n

3. Reduce pressurizer pressure to < 1837 psia. Reduce RCS Te to < 485°F. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2.3 3.5.3-1 AfVlENDMENT NO. W-.

ECCS Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify 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.

31 days SR 3.5.3.2 Verify ECCS piping is full of water. 31 days SR 3.5.3.3 Verify each ECCS pump develops the required differential pressure at the flow test point. In accordance with the Inservice Testi ng Program SR 3.5.3.4 Verify each ECCS automatic valve that is not locked, sealed, or otherwise secured in position.

in the flow path actuates to the correct position on an actual or simulated actuation signal. 18 months SR 3.5.3.5 Verify each ECCS pump starts automatically on an actual or simulated actuation signal. 18 months SR 3.5.3.6 Verify each LPSI pump stops on an actual or simulated actuation signal. 18 months PALO VERDE UNITS 1.2.3 3.5.3-2 AMENDMENT NO.

3.5.3 ECCS Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.7 Verify. for each throttle valve listed below. each position stop is in correct posltion.

18 months LPSI System lve Number Leg Injection Valve Numbers SIB-UV 615 SIB-UV 625 SIA-UV 635 SIA-UV 645 S HV 306 SIB HV 307 SIC HV 321 SID HV 331 SR 3.5.3.8 Verify. by visual inspection.

each ECeS 18 months train containment sump suction inlet is not restricted by debris and the suction inlet strairers show no evidence of structural distress or abnormal corrOSlon.

PALO VERDE UNITS 1.2.3 3.5.3-3 AMENDMENT NO. .

ECCS Shutdown 3.5.4 3.5 CORE COOLING SYSTEMS (ECCS) 3.5.4 ECCS Shutdown LCO 3.5.4 One High Pressure Safety Injection (HPSI) train shall be OPERABLE.

APPLICABILITY:

MODE 3 with pressurizer pressure < 1837 psia and with RCS < 485°F. MODE 4. ACTIONS -----------------------NOTE -------------------

LCO 3.0.4.b is not applicable to ECCS High Pressure Safety Injection subsystem when entering MODE 4. CONDITION REQUIRED ACTION COMPLETION TIME A. Required HPSI train inoperable.

A.1 Restore required HPSI train to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B. Required Action and associated Completion Time not met. B.1 Be in MODE 5. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SURVEILLANCE SR The following SRs are applicable:

SR 3.5.3.1 SR 3.5.3.5 SR SR 3.5.3.7 SR SR 3.5.3.8 SR 3.5.3.4 FREQUENCY In accordance with applicable SRs PALO VERDE UNITS 3.5.4-1 AMENDMENT NO. +/-+/-+,

RWT 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Refueling Water Tank (RWT) LCO 3.5.5 The RWT shall be OPERABLE.

APPLICABILITY:

MODES 1. 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWT boron concentration not withi n 1 i mits . OR-RWT borated water temperature not within 1 imits. A.1 Restore RWT to OPERABLE status. 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> B. RWT inoperable for reasons other than Condition A. B.1 Restore RWT to OPERABLE status. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion T-j me not met. AND -C.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1,2,3 3.5.5-1 AMENDMENT NO.

RWT 3,5,5 SURVEILLANCE REQUIREMENTS SR 3,5,5,1 SURVEILLANCE Only required to be performed when ambient air temperature is < 60°F or > 120°F. Verify RWT borated water temperature is ;::: 60°F and $120°F, FREQUENCY 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SR 3,5,5.2 Verify RWT borated water volume is ;::: minimum required RWT volume in Figure 3,5.5-1. 7 days SR 3,5,5.3 Verify RWT boron concentration is ;::: 4000 ppm and $ 4400 ppm. 7 days PALO VERDE UNITS 1,2.3 3.5,5-2 AMENDMENT NO, RWT Pre-RWT TS Setpoint Change 3.5.5 624,000 GAL 183% (565"F)85% 80% w :It C) ::>75%z ...J C g 550,000<C I-Z w AVERAGE ReS TEMPERATURE (pF) F 3.5. Minlmum Required RWT 601,000 )79.9% (2,..F) 525,000:It 70% ::> en ...J W >W ...J 0 o 100 200 300 400 500 600 PALO VERDE UN 1. 2.3 3 553 AMENDMENT NO. !++

RWT After RWT TS Setpoint Change 3.5.5 634.000 GAL (565'F) 611.000 GAL 181.2°Q (21 OfF) 650.000\ 625.000<!l 75°. z 15 <;t w a:: z w :i 70*. ::>a:: z ...J W > W ...J 600.000 575.000 w :i :::l ..J g 550.000 l-s: a:: 525.000 500.000 475.000 ____________o 100 200 300 400 500 600 AVERAGE Res TEMPERATURE (oF) FIGURE 3.5.5 Mlnimum Required PALO VERDE UNITS 1.2.3 3.5.5-4 AMENDMENT NO. 182 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS 3.5.6 Trisodium Phosphate LCO 3.5.6 The TSP baskets shall contain 524 ft 3 of active APPLI CAB I L ITY: MODES 1, 2. and 3. ACTIONS COND ION REQUIRED ACTION COMPLETION TIME A. TSP not within limits. A.l Restore TSP to within 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> limits. B. Required Action and B.l associated Completion T-i me not met. AND-B.2 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> Be in MODE 4. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.5.6.1 Verify the TSP baskets contain 524 ft 3 of granular anhydrous trisodium phosphate.

18 months SR 3.5.6.2 Verify that a sample from the TSP baskets provides adequate pH adjustment of borated water. 18 months PALO VERDE UNITS 1.2.3 3.5.6 1 AMENDMENT NO.

Containment 3.6.1 3.6 CONTAINMENT 3.6.1 LCO 3.6.1 Containment shall be APPLI CABI LITY: MODES 1. 2. 3. and REQUIRED ACTION COMPLETION TIME A. Containment inoperable.

B. Required Action and associated Completion Time not met. A.l B.1 AND-B.2 Restore containment to OPERABLE status. Be in

3. Be in

5. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and leakage rate testing except for containment air lock testing, in accordance with the Containment Leakage Rate Testing Program. In accordance with the Containment Leakage Rate Testing Program SR 3.6.1. 2 Verify containment structural integrity in accordance with the Containment Tendon Surveillance Program. In accordance with the Containment Tendon Surveillance Program PALO VERDE UNITS 1.2.3 3.6.1-1 AMENDMENT NO.

Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS ------------------------NOTES --------------------Entry and exit is permissible to perform repairs on the affected air lock components. Separate Condition entry is allowed for each air lock. Enter applicable Conditions and Required Actions of LCO 3.6.1. "Containment." when leakage results in exceeding the overall containment leakage rate acceptance criteria.

CONDITION REQU I RED ACTI ON COMPLETION TIME A. One or more containment air locks with one containment ai r lock door inoperable.

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. (continued)

PALO VERDE UNITS 1,2.3 AMENDMENT NO.

---

---

3.6.2 Containment Air Locks ACTIONS COI'1PLETION REQUIRED ACTION CONDITION A.1 Verify the OPERABLE 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> door is closed in the affected air lock. A. (continued)

AND-A.2 Lock the OPERABLE 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> door closed in the affected air lock. AND -A.3 Air lock doors in high radiation areas may be verified locked closed by administrative means. Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock. B. One or more containment air locks l. Required Actions with containment B.2. and B.3 are lock applicable if both doors mechanism inoperable.

in the same air lock are inoperable and Condition C is entered. Entry and exit of containment is permissible under the control of a dedicated individual. (cont'inued)

PALO VERDE UNITS 1.2.3 AMENDMENT NO.

3.6.2 Containment Air Locks ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B, (continued)

B,l AND-B,2 AND-B.3 Verify an OPERABLE door is closed in the affected air lock, Lock an OPERABLE door closed in the affected air lock.

Air lock doors in high radiation areas may be verified locked closed by administrative means. Verify an OPERABLE door is locked closed in the affected air lock. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> Once per 31 days C. One or more containment air locks inoperable for reasons other than Condition A or B. C.1 AND-C.2 AND-C.3 Initiate action to evaluate overall containment leakage rate per LCD 3.6.1. Verify a door is closed in the affected air lock. Restore air lock to OPERABLE status. Immediately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> (continued)

PALO VERDE UNITS 1,2,3 3.6.2 3 AMENDMENT NO. 117 Containment Air Locks 3.6.2 ACTIONS (continued)

REQUIRED ACTION COMPLETION TIME CONDITION 6 associated Compl Time not D. Requi red Acti on and 0.1 Be in MODE 3. AND 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> 0.2 Be in MODE 5. SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.6.2.1 ------NOTES 1. An inoperable air lock door does not invalid the previous successful performance of the overall air lock 1 eakage test. 2. Resul shall be evaluated against acceptance criteria applicable to SR 3.6.1.1. Perform required air lock leakage rate testing in accordance with the Containment kage Rate Testing Program. In accordance with the Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at a time. 24 months PALO VERDE UNITS 1.2.3 3.6.2-4 AMENDMENT NO.

Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each required containment isolation valve shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS ---------------------NOTES-------

-

on flow paths except for 42 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condi on entry is allowed for each penetration flow path. 3. Enter applicable Conditions and Reqlxired Actions for system(s) made inoperable by containment isolation valves. 4. Enter applicable Conditions and Required Actions of LCO 3.6.1,"Containment," when leakage results in exceeding the overall containment leakage rate acceptance criteria.

5. A 42 inch refueling purge valve is not a required containment isolation valve when its flow path is isolated with a blind flange tested accordance with SR

1. CONDITION REQUIRED ACTION COMPLETION TIME A. --------NOTE --------A. 1 Isolate the affected 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> Only applicable to penetration flow path penetration flow paths by use of least with two required one closed and containment isolation de-activated valves. automatic valve, closed manual valve. blind flange, or One or more check valve with flow penetration flow paths through the valve with one required secured. containment isolation valve inoperable AND except for purge valve leakage not within 1 imit. (continued)

PALO VERDE UNITS 1,2,3 3.6.3 1 AMENDMENT NO. +/-+/-+,

3.6.3 Containment Isolation Valves ACTIONS COND ON REQUIRED ACTION COMPLETION TIME A. (continued)

A.2 --------NOTE Isolation devices in high radiation areas may be verified by use of administrative means. ------_ ..... --Verify the affected penetration flow path is isolated.

Once per 31 days for isolation devices outside conta-j nment AND -Prior to entering MODE 4 from MODE 5 if not performed withi n the previous 92 days for isolation devices inside containment B. -----Only applicable to penetration flow paths with two requ-j red containment isolation valves.

One or more penetration flow paths with two required containment isolation valves inoperable except for purge valve leakage not within 1 i mit. B.1 Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve. closed manual valve, or blind flange. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (continued)

PALO VERDE UNITS 1,2,3 3.6.3-2 NO. , 166 3.6.3 Containment Isolation Valves ACTIONS (continued)

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

One or more penetration flow paths with one required containment isolation valve inoperable.

C.1 AND -C.2 REQUIRED ACTION Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve. closed manual valve. or blind flange.

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

Verify the affected penetration flow path is isolated.

COMPLETION TIlvlE 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> Once per 31 days D. One or more penetration flow paths with one or more required containment purge valves not within purge valve leakage limits. 0.1 AND -Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve with resilient seals. or blind flange. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> (continued)

PALO VERDE UNITS 1.2.3 3.6.3-3 At"IENDMENT NO. W.

---

3.6.3 Containment Isolation Valves ACTIONS I COMPLETION TIME REQUIRED ACTION CONDITION D. (continued)

D.2 ----

Isolation devices in high radiation areas may be verified by use administrative means. Once per 31 days penetration flow path Verify the affected for isolation is isolated.

devices outside containment AND-Prior to entering MODE 4 from 5 if not performed within the previous 92 days for isolation devices inside containment AND Once per 92 days for the resilient seal purge valves closed to comply with Required Action 0.1. 0.3 Perform SR 3.6.3.6 E. Required Action and E.l Be in MODE 3. 6 associated Time not AND E.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1.2.3 3.6.3-4 AMENDMENT NO.

3.6.3 Containment Isolation Valves SURVEILLANCE REQUIREMENTS SR 3.6.3.1 SURVEILLANCE Verify each required 42 inch purge valve 1S sealed closed except for one purge valve in a penetration flow path while in Condition D of this LCD. FREQUENCY 31 days SR 3.6.3.2 Verify each 8 inch purge valve is closed except when the 8 inch purge valves are open for pressure control. ALARA or air quality considerations for personnel entry. or for Surveillances that require the valves to be open. 31 days SR 3.6.3.3 -----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 outside containment and not locked, sealed or otherwise secured and is required to be closed during accident conditions is closed, except for containment isolation valves th are open under administrative controls.

31 days PALO VERDE UN 1.2.3 3.6.3-5 AMENDMENT NO. +/-+/-+,

3.6.3 Containment Isolation Valves SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.3.4 SURVEILLANCE Valves and blind flanges in high areas may be verified by use of administrative means. radiation 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.

FREQUENCY Prior to entering MODE 4 from MODE 5 if not performed withi n the previous 92 days SR 3.6.3.5 Verify the isolation time of each required automatic power operated containment isolation valve is within limits. In accordance with the Inservice ng Program SR 3.6.3.6 Perform 1 eakage rate testi ng for requ-j red containment purge valves with resilient seals. 184 days Within 92 days after opening the valve SR 3.6.3.7 Verify each required 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. 18 months PALO VERDE UNITS 1,2,3 3.6.3-6 AMENDMENT NO. +/-+/-+,

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment LCO 3.6.4 Containment pressure shall be 0.3 psig and $ .5 APPLICABILITY:

MODES 1. 2. 3. and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION A. Containment pressure not within limits. A.l Restore containment pressure to within limits. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B. Required Action and aSSOCiated Completion Time not met. B.l AND-B.2 Be in MODE 3. in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> 1 imits. PALO VERDE UNITS 1.2,3 3.6.4-1 AMENDMENT NO.

Containment Air Temperature 3.6.5 3.6 CONTAINMENT 3.6.5 Containment Air LCO 3.6.5 Containment average air temperature shall be s APPLICABILITY' MODES 1, 2, 3, and CONDITION REQUIRED ACTION COMPL ION TIME A. Containment average air temperature not within 1 imit. A.1 Restore containment average air temperature to within 1 imit. 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> B. Required Action and associated Completion Time not met. B.1 AND-B.2 Be in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> is with in 1 i mit . PALO VERDE UNITS 1,2,3 3.6.5-1 AMENDMENT NO.

Containment Spray System 3.6.6 3.6 CONTAINIVIENT 3.6.6 Containment Spray LCO 3.6.6 Two containment spray trains shall be APPLI CAB I LI TY : MODES 1. 2. and 3. MODE 4 when RCS pressure is 385 psia ACTIONS CONDITION REQUIRED ACTION COMPLETION TII"IE A. One containment spray train inoperable.

A.1 Restore containment spray train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Required Action and associated Completion me of Condition A not met. B.1 AND-B.2 Be in MODE 3. Be in MODE 4 with RCS pressure < 385 psia. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 84 hours3.5 days <br />0.5 weeks <br />0.115 months <br /> C Two containment spray trains inoperable.

C.1 Enter LCO 3.0.3. Immediately PALO VERDE UNITS 1.2,3 3.6.6-1 AMENDMENT NO.

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power operated.

and automatic valve in the flow path that is not locked, sealed. or otherwise secured in position is in the correct position.

31 days SR 3.6.6.2 Verify the containment spray piping is full of water to the 113 ft level in the containment spray header. 31 days SR 3.6.6.3 Verify each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head. In accordance with the Inservice Testing Program SR 3.6.6.4 Verify each automatic containment spray 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. 18 months SR 3.6.6.5 Verify each containment spray pump starts automatically on an actual or simulated actuation signal. 18 months SR 3.6.6.6 Verify each spray nozzle is unobstructed.

10 years PALO VERDE UNITS 1.2,3 3.6.6-2 AMENDMENT NO.

MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) LCO 3.7.1 The MSSVs shall be OPERABLE as specified in Table 3.7.1-1 and Table 3.7.1-2. APPLI CAB I L ITY : MODES 1. 2. and 3 ACTIONS --------------

---

NOTE--Separate Condition entry is allowed for each MSSV. CONDITION REQU I RED ACTI ON COMPLETION TIME A. One to four required MSSVs per steam generator inoperable in MODES 1 or 2. A.l AND-A.2 Reduce power to less than or equal to the applicable

%RTP listed in Table 3.7.1 l. Reduce the variable overpower trip -high setpoint in accordance with Table 3.7.1-l. 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> B. Required Actions and associated Completion Times of Condition A not met. OR-Five to eight required MSSVs per steam generator inoperable in MODES 1 or 2. B.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> (Cont-j nued) PALO VERDE UNITS 1.2.3 3.7.1 1 AMENDMENT NO. +/-+/-7, 155 MSSVs 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and associated Completion Time of Condition B not met. C.1 in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> D. More than eight required MSSVs per steam generator inoperable.

0.1 AND-0.2 Be in MODE 3. in MODE 4. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNI 1.2.3 3.7.1 2 NO. ill. 155 3.7.1 MSSVs SURVEILLANCE REQUIREMENTS SR -----------

---

NOTE---------

---Not required to be performed prior to entry 'j nto MODE 3. Verify each required MSSV lift setpoint per Table 3.7.1-2 in accordance with the Inservice Testing Program. Following testing, lift settings shall be within +/- 1%.

In accordance with the Inservice Testing Program PALO VERDE UNITS 1,2,3 3.7.1-3 AMENDIVIENT NO. ill, 155 MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)Variable Overpower Trip Setpoint versus OPERABLE Maln Steam Safety Valves MINIMUM NUMBER OF MSSVs PER STEAM GENERATOR REQUIRED OPERABLE NUMBER OF INOPERABLE MSSVs PER STEAM GENERATOR MAXIMUM POWER (% RTP) or HIGHEST MODE MAXIMUM ALLOWABLE VARIABLE OVERPOWER TRIP SETPDINT 1a ) C% RTP) 10 0 9 1 8 2 7 3 6 4 5 5 100.0 90.0 80.0 68.0 56.0 MODE 3 MODE 3 3 111. (a) The VOPT setpoint IS not required to be in MODE 3. PALO VERDE UNITS 1.2.3 3.7.1-4 AMENDMENT NO. +&7.

MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)Main Steam Safety Valve Lift Settings VALVE NUMBER LI FT SETTING (psig +/- 3%)Steam Generator

1. 1 Steam Generator

1. 2 SGE PSV 572 SGE PSV 579 SGE PSV 573 SGE PSV 578 SGE PSV 574 SGE PSV 575 SGE PSV 576 SGE PSV 577 SGE PSV 691 SGE PSV 692 SGE PSV 554 SGE PSV 561 SGE PSV 555 SGE PSV 560 SGE PSV 556 SGE PSV 557 SGE PSV 558 SGE PSV 559 SGE PSV 694 SGE PSV 695 1250 1250 1290 1290 1315 1315 1315 1315 1315 PALO VERDE UNITS 1.2.3 3.7.1-5 AMENDMENT NO. +/-+/-+.

MSIVs 3 7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs) LCO Four MSIVs and their associated actuator trains shall be OPERABLE.

MODE 1, MODES 2. 3, and 4 except when all MSIVs are closed and deactivated.

ACTIONS A. CONDITION One MSIV with a single actuator train inoperable.

A.1 REQUIRED ACTION Restore MSIV actuator train to OPERABLE status COMPLETION TIME 7 days B. Two MSIVs each with a single actuator train inoperable such that the inoperable trains are not in the same instrumentation train. B.1 Restore one MSIV actuator train to OPERABLE status hours C. Two MSIVs each with a single actuator train inoperable and both inoperable actuator trains are in the same instrumentation train. C.1 Restore one MSIV actuator train to OPERABLE status 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> D. Two actuator trains for one MSIV inoperable.

0.1 Declare the affected MSIV inoperable.

Immediately

" (continued)

PALO VERDE UNITS 3.7.2-1 AMENDMENT NO.+/-§g.

3.7.2 MSIVs ACTIONS (continued)

E. CONDITION Three or more MSIV actuator trains inoperable.

OR-Required Action and associated Completion Time of Condition A. B, or C not met. E.l REQU I RED ACTI ON Declare each affected MSIV inoperable.

COMPLETION Immediately ME F. One MSIV MODE 1. inoperable in F.l Restore MSIV to OPERABLE status. 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> G. H. Required Action and Associated Completion Time of Condition F not met. ------NOTE Separate Condition entry is allowed for each MSIV. One or more MSIVs inoperable in MODE 2, 3. or 4. G.l H.l AND-H.2 in MODE 2. Close MSIV. Verify MSIV is closed. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> Once per 7 days 1. Required Action and associated Cornpl on Time of Condition H not met. 1.1 AND -1.2 Be in MODE Be in MODE 3. 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1.2.3 3.7.2-2 AMENDMENT NO. +++.

3.7.2 SURVEILLANCE SR --------NCTE -Not required to be performed prior to entry into MODE 3. Verify closure time of each MSIV is within limits with each actuator train on an actual or simulated actuation signal. MS Vs In accordance with the Inservice Testing Program PALO VERDE UNI 1.2.3 3.7.2-3 AMENDMENT NO. +/-eJ 181 MFIVs 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs) LCO Four economi zer and four downcomer MFIVs shall be OPERABLE.

MODES 1. 2, 3, and 4 except when MFIV is closed and' deactivated or isolated by a closed and deactivated power operated valve. ACTIONS ---------------------------

NOTE-------

---

Separate Condition entry is allowed for each penetration flow path. CONDITION REQUI RED ACTI ON COMPLETION TIME A. One or more MFIVs -j noperab 1e . A.1 AND-A.2 Close or isolate 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> i noperab 1 e MFIV. Verify inoperable Once per 7 days MFIV is closed or isolated.

B. Two valves in the same ow path inoperable.

B.1 AND B.2 Isolate affected flow 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> path. Verify inoperable MFIV is closed or Once per 7 days isolated.

PALO VERDE UN 3.7.3-1 AMENDMENT NO. l+/-7 MFIVs 3.7.3 ACTIONS (continued)

COND ON REQUI ACTION COMPLETION TIME C. Requi red Acti on and associ ated Compl lOn Time not met. C.1 AND C.2 in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SR 3.7.3.1 Verify closure time each is within limlts on an actual or simul actuation slgnal.

In accordance with the Inservice Tes ng Program PALO VERDE UNITS 1,2,3 3.7.3-2 AMENDMENT NO. ++/-+

ADVs 3.7.4 3.7 PLANT 3.7.4 Atmospheric Dump Valves LCO 3.7.4 One ADV line per steam generator shall be APPLICABILITY:

MODES 1. 2. and MODE 4 when steam generator is being relied upon for heat removal. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ADV line inoperable.

A.1 Restore ADV line to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Two required ADV lines inoperable.

B.1 Restore one ADV line to OPERABLE status. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. Required Action and associated Completion Time not met. C.1 AND-C.2 Be in MODE 3. Be in MODE 4 without reliance on steam generator for heat removal. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> PALO VERDE UNITS 1.2,3 3.7.4-1 AMENDMENT NO. 1++,

3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ADV. 18 months PALO VERDE UNITS 1,2,3 3.7.4-2 AMENDMENT NO.

3.7.5 AFW 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCD 3.7.5 Three AFW trains shall OPERABLE. Only one AFW train. which includes a motor driven pump.required to be OPERABLE in 1'10DE 4. is APPLICABILITY:

MODES 1. 2. and 3, MODE 4 when steam generator is relied upon for heat rem oval. ACTIONS ---NOTE LCO 3.0.4.b is not COND ON REQUIRED ACTION COMPLETION TIME A One steam supply to turbine driven AFW pump inoperable.

OR --Only applicable if MODE 2 has not been entered following refueling.

---

One turbine driven AFW pump inoperable in MODE 3 following refueling.

A.1 Restore affected equipment to OPERABLE status. 7 days AND-10 days from discovery of fail ure to meet the LCO B. One AFW train inoperable for reasons other than Condition A in MODE 1. 2. or 3. B.1 Restore AFW train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> AND-10 days from di scovery of failure to meet the LCO (continued)

PALO VERDE UNITS 1.2.3 3.7.5-1 AMENDMENT NO. +/-J4. 165 3.7.5 AFW System ACTIONS (continued)

C. COND ION Required Action and associated Completion Time of Condition A or B not met. OR -Two AFW trains inoperable in MODE 1. 2, or 3 C.1 AND -C.2 REQUIRED ACTION Be in MODE 3. Be in MODE 4. COMPLETION TIME 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> D. E.' Three AFW trains inoperable in MODE 2, or 3. Required AFW train inoperable in MODE 1. 4. 0.1 E.l -----NOTE -LCD 3.0.3 and all other LCD Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status. Initiate action to restore one AFW train to OPERABLE status. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status. Initiate action to restore one AFW train to OPERABLE status. Immediately Immediately PALO VERDE UNITS 1,2,3 3.7.5 2 AMENDMENT NO.

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated.

and 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.

31 days SR 3.7.5.2 -Not required to be performed for the turbine driven AFW pump until 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> after reaching 532°F in the RCS. Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head. In accordance with the Inservice Test Program SR 3.7.5.3 1. Not required to be performed for the turbine driven AFW pump until 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> after reaching 532°F in the RCS. 2. Not app 1 i cab 1 e in MODE 4 when steam generator is relied upon for heat removal. Verify each AFW automatic valve that is not 18 months locked. sealed. or otherwise secured in position.

actuates to the correct position on an actual or simulated actuation signal.

PALO VERDE UNITS 1. 2,3 3.7.5-3 AMENDMENT NO.

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.5.4 ------------NOTES --1. Not requi red to be performed for the turbine driven AFW pump until 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> after reaching 532°F in the RCS. Not applicable in MODE 4 when steam generator is relied upon for heat removal. Verify each AFW pump starts automatically 18 months on an actual or simulated actuation signal. SR 3.7.5.5 Verify the proper alignment of the required AFW flow paths by verifying flow from the condensate storage tank to each steam generator.

Prior to entering MODE 2 whenever unit has been in MODE 5 or 6 for > 30 days PALO VERDE UNITS 1,2,3 AMENDMENT NO.

CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST) LCO 3.7.6 The CST level shall be 29.5 APPLICABILITY:

MODES L 2. and 3. MODE 4 when steam gene rator is relied upon for heat removal. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST level not withi n 1 i mit. A.1 AND-A.2 Verify OPERABILITY of backup water supply. Restore CST level to within limit 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> AND-Once per 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> thereafter 7 days B. Required Action and associated Completion Time not met. B.1 AND-Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> B.2 Be in MODE 4 without reliance on steam generator for heat removal. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SURVEILLANCE SR 3.7.6.1 SURVEILLANCE Verify CST level is 29.5 ft. FREQUENCY 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> PALO VERDE UNITS 1.2.3 3.7.6 1 AMENDMENT NO.

EW System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Essential Cooling Water ( ) System LCO 3.7.7 Two EW trains shall be OPERABLE.

APPLICABILITY:

MODES 1. 2. 3. and 4. ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TH'IE A. One EW train inoperable.

A.l -----NOTE Enter applicable Conditions and Required Actions of LCD 3.4.6. "RCS Loops MODE 4" for shutdown cooling made inoperable by EW. Restore EW train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Required Action and associated Completion Time of Condition A not met. B.l AND -Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> B.2 Be in MODE 5 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1.2,3 3.7.7-1 AMENDMENT NO.

3.7.7 EW System SURVEILLANCE REQUIREMENTS SR 3.7.7.1 SURVEI LLANCE Isolation of EW flow to individual components does not render tile EW System inoperable.

Veri fy each EW

1. power operated.

and 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.

FREQUENCY 31 days SR 3.7.7.2 Verify each EW 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. 18 months SR 3.7.7.3 Verify each EW pump starts automatically on an actual or simulated actuation signal. 18 months PALO VERDE UNITS 1.2.3 3.7.7-2 AMENDMENT NO.

ESPS 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Essential Spray Pond System (ESPS) LCO 3.7.8 Two ESPS trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CDND ION REQUIRED ACTION COMPL ION TIME A. One ESPS train inoperable.

A.l

1. Enter applicable Condi ons and Required Actions of LCO 3.8.1. "AC Sources -Operatlng, " for emergency diesel generator made -j noperab 1 e by ESPS. 2. Enter applicable Conditions and Required Actions of LCO 3.4.6. "RCS Loops -MODE 4," for shutdown cooling made inoperable by ESPS. -Restore ESPS train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Required Action and associated Completion Time of Condition A not met. B.l AND-Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> B.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> PALO VERDE UNITS 1,2,3 3.7.8-1 AMENDMENT NO.

ESPS 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Isolation of ESPS flow to individual components does not render ESPS inoperable.

Verify each ESPS manual and power operated valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

31 days SR 3.7,8.2 Verify each ESPS pump starts automatically on an actual or simulated actuation signal. 18 months PALO VERDE UNITS 1.2,3 3.7.8-2 AMENDMENT NO.

LlHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS) LCD 3.7.9 The UHS shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS CONDITION REOU I RED ACTI ON COMPLETION TIME A. UHS inoperable.

A.l Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> AND A.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEI LLANCE FREQUENCY SR 3.7.9.1 Verify the usable water depth of each essential spray pond is 12 feet. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> SR 3.7.9.2 Verify water temperature of each essential spray pond is 89°F. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> PALO VERDE UNITS 1,2,3 3.7.9-1 Atv'IENDMENT NO.

3.7 PLANT SYSTEMS 3.7.10 Essential Chilled Water (EC) System LCO 3.7.10 Two EC trains shall be OPERABLE.

APPLICABI LITY: MODES 1. 2. 3. and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One EC train inoperable.

A.l Restore EC train to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. Required Action and associated Completion Time not met. B.l AND-B.2 Be in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify each EC System manual. power operated.

and automatic valve 'in the flow path. that is not locked. sealed. or otherwi se secu red in pos it ion, is "i n the correct position.

31 days SR 3.7.10.2 Verify the proper actuation of each EC System component on an actual or simulated actuation signal. 18 months PALO VERDE UNITS 1.2,3 3.7.10-1 AMENDMENT NO.

CREFS 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Control Room sential ltration System (CREFS) LCD 3.7.11 Two CREFS trains shall be OPERABLE.

---

NOTE--------The Control Room Envelope (CRE) boundary Illay be opened intermittently under administrative control. APPLICABILITY:

MODES 1. 2, 3, 4. 5, and 6. During movement of irradiated fuel assemblies, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRE train inoperable for reasons other than Condition B. A.1 Restore CREFS train to OPERABLE status. 7 days B. One or more CREFS trains inoperable due to inoperable CRE boundary in MODE 1, 2, 3, or 4. B.1 AND-B.2 AND-B.3 Initiate action to implement mitigating actions. Verify mitigating actions ensure CRE occupant exposures will not exceed radiological limits and that CRE occupants are protected from smoke and potential chemical hazards. Restore CRE boundary to OPERABLE status. Immediately 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> 90 days (continued)

PALO VERDE UNITS 1.2.3 3.7.11-1 NO. +/--J:..7..

171 CREFS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.l Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion Time of Condition A or AND-B not met in MODE 1. 2. 3, or 4. C.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> D. Required Action and associated Completion Time of Condition A not met in MODE 5 or 6. 0.1 Place OPERABLE CREFS train in operation.

Immediately E. Required Action and associated Completion Time Condition A not met during movement of i rradi ated fuel assemblies.

E.1 OR E.2 Place OPERABLE CREFS Train in operation.

Suspend movement of i rradi ated fuel assemblies.

Immediately Immediately F. Two CREFS trains inoperable in MODE 5 or 6, or during movement of i rradi ated fuel assemblies.

F.1 AND -Suspend CORE AL TERA TI ONS . Immediately OR -One or more CREFS trains inoperable due to inoperable CRE boundary in MODE 5 or 6. or during movement of irradiated fuel assemblies.

F.2 Suspend movement of i rradi ated fuel assemblies.

Immediately G. Two CREFS trains inoperable in MODE 1. 2, 3, or 4, for reasons other than Condition B. G.l Enter LCO 3.0.3. Immediately (continued)

PALO VERDE UNITS 1,2.3 3.7. -2 AMENDMENT NO. +/-+/-+, 171 CREFS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each CRE train for 15 minutes. 31 days SR 3.7.11.2 Perform required CREFS filter testing in accordance with the Ventilation lter Testing Program (VFTP). In accordance with the VFTP SR 3.7.11.3 Verify each CREFS train actuates on an actual or simulated actuation signal. 18 months SR 3.7. .4 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program. In accordance with the Control Room Envelope Habitability Program. PALO VERDE UNITS 1.2.3 3.7. 3 AMENDMENT NO. +/-+/-+.

CREATCS 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Control Room rgency Air Temperature Control System (CREATCS)

LCO 3.7.12 Two CREATCS trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDI ON REQUIRED ACTION COMPLETION TIME A. One CREATCS train 'j noperab 1 e. A.1 Restore CREATCS train to OPERABLE status. 30 days B. Required Action and associated Completion Time of Condition A not met in MODE 1. 2. B.l AND-Be in MODE 3: 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 3. or 4. B.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> C. Required Action and associated Completion Time of Condition A not met in MODE 5 or 6. C.1 Place OPERABLE CREATCS train in operation.

Immedi y D. Required Action and associated Completion me of Condition A not met during movement of irradiated fuel assemblies.

D.1 OR-D.2 Place OPERABLE CREATCS train in operation Suspend movement of i rradi ated fuel assemblies.

Immedi y Immediately PALO VERDE UNI 1.2.3 3.7.12-1 AMENDMENT NO.

CREATCS 3.7.12 ACTIONS (continued)

COND ON REQUIRED COMPL ION TItvlE E. Two CREATCS trains inoperable in MODE 5 or 6, or during movement of irradiated fuel assemblies.

E.1 AND-E.2 Suspend CORE AL TERATIONS.

Suspend movement of irradiated fuel assemblies.

Immediately Immediately F. Two CREATCS trains inoperable in MODE 1. 2. 3. or 4. F.1 Enter LCD 3.0.3. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7 ..1 Verify each CREATCS train has the 18 months capability to remove the assumed heat load. PALO VERDE UNITS 1.2.3 3.7.12 2 AMENDMENT NO.

F PREACS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Engineered Safety Feature ( F) Pump Room Exhaust Air Cleanup System (PREACS) LCO 3.7.13 Two ESF PREACS trains shall be OPERABLE.

AP ICABILITY:

MODES 1. 2,3. and 4. ACTIONS CONDITION REQUIRED ACTION t"'r\ 'f"\ ION

\JUIII A. One PREACS train -j noperab 1 e. A.l Restore ESF PREACS train to OPERABLE status. 7 days B. Required Action and associated Completion Time not met. B.l AND B.2 Be in MODE 3. Be in MODE 5. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.13.1 Operate each F PREACS train for 31 days 15 m-j nutes PALO VERDE UNITS 1.2.3 3.7.13-1 AMENDMENT NO.

F PREACS 3.7.13 SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.13.2 SURVEILLANCE Perform required ESF PREACS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). FREQUENCY In accordance with the VFTP SR 3.7.13.3 Verify each PREACS train actuates on actual or simulated actuation signal. an 18 months SR 3.7.13.4 Verify one PREACS train can maintain measurable negative pressure relative to atmospheric pressure during operation at flowrate of 6000 cfm 0%. a a 18 months STAGGERED BASIS on a PALO VERDE UNITS 1,2,3 3.7.13-2 AMENDMENT NO.

Fuel Storage Pool Water Level 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Water Level LCO 3.7.14 The fuel storage pool water level shall be 23 over the top of irradiated fuel assemblies seated in the storage racks. APPLICABILITY:

During movement of irradiated fuel assemblies in the fuel storage pool. ACTIONS CONDITION REQU I RED ACTI ON I CCiMPLI::TION TIME A. Fuel storage pool water level not within 1 imit. A.l LCO 3.0.3 is not applicable.

Suspend movement of irradiated fuel assemblies in fuel storage pool. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the fuel storage pool water level is 7 days 23 ft above the top of irradiated fuel assemblies in the storage racks. PALO VERDE UNITS 1,2,3 3.7.14-1 AMENDMENT NO.

Fuel Storage Pool Boron Concentration 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Storage Pool Boron Concentration LCO The fuel storage pool boron concentration shall be ;::: 2150 ppm.

Whenever any fuel assembly is stored in the fuel storage pool. ACTIONS REQUIRED ACTION TIME A. Fuel storage pool boron concentration not within limit. LCO 3.0.3 is not applicable.

A.l AND Suspend movement of fuel assemblies in the fuel storage pool. A.2 Initiate action to restore fuel storage pool boron concentration to with i n 1 i mit. Immediately Immediately PALO VERDE UN 1. 3.7.15-1 AMENDMENT NO. ,

Fuel rage Pool Boron Concentration 3.7.15 SURVEILLANCE FREQUENCY SURVEILLANCE 7 days SR 3.7.15.1 Verify the fuel storage pool boron concentration is within limit. PALO VERDE UNITS 1.2.3 3.7.15 2 AMENDMENT NO.

Secondary Speci c Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Speci c Activity LCO The specific activity of the secondary coolant shall be 0.10 vCi/gm DOSE EQUIVALENT 1-131. APPLICABILITY:

1. 2, 3, and 4. ACTIONS CONDI ON REQUIRED ACTION COMPL ION TIME A. Specific activity not with'j n 1 i mit. A.l AND Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> A.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the 31 days secondary coolant is within limit. PALO VERDE UN 1.2,3 AMENDMENT NO.

Spent Fuel Assembly Storage 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Spent Fuel Assembly Storage LCO 3.7.17 The combination of ini al enrichment.

burnup. and decay time of each fuel assembly stored in each of the four regions of the fuel storage pool shall be within the acceptable burnup domain for each region as shown in Figures 3.7.17 1. 3.7.17-2.

or 3.7.17-3, and described in Specification 4.3.1.1. APPLICABILITY:

Whenever any fuel assembly is stored in the fuel storage pool. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the LCO not met, A.l LCO 3.0.3 is not applicable.

Initiate action to move the noncomplying fuel assembly into an appropriate region. Immediately SURVEILLANCE SR Verify by administrative means the initial enrichment, burnup, and decay time of the fuel assembly is in accordance with Figures 3.7.17 1. 3.7.17-2.

or 3.7.17 3. and Specification 4,3.1.1.

Prior to storing the fuel assembly in the fuel storage pool. PALO VERDE UNITS 3.7.17 1 AMENDMENT NO, +/-+/-+.

• * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *

• Spent Fuel Assembly Storage 3.7.17 Figure 3.7.17 ASSEMBLY BURNUP VERSUS INITIAL Region 20000 I! 2.0 2.5 3.0 3.5 4.0 Initial Enrichment.

weight % I AccbpTABUfor Reg 1 15000 !j I **** on2 * &

• NOT AfCEPTAI LE for R1giOn 2 I I * \ \ /5000 ! 1 j Note: This I o *

• 1.5 4.5 : 5.0 4.800/0 limiting enrichment PALO VERDE UNITS 1.2.3 3.7.17-2 AMENDMENT NO. +/-l+. 125

• * * * *

• Spent Fuel Assembly Storage 3.7.17 Figure ASSEMBLY BURNUP VERSUS INITIAL Region (at decay times from 0 to 20 45ooo,..-----,----,-----;----,-----,..----,-----.

---

,

• ____4

> I ACCEP for Region 3 ******* ****

• • 25000 ------+--------1----

0. :::l E :::l tIl >. 20000

c E II) NOT ACCEPTAB E for Re ion 3<< 15000

• ytime. : **

• • *1.5 2.0 2,5 3,0 3.5 4.0 4.5 *** 5.0 Initial Enrichment, weight % 4.80% limiting Decay lime ___y_q_rS___---__5

____

__ _______________PALO VERDE UNITS 1.2.3 3.7. 3 AMENDMENT NO.

• * * * * * * * *

• 45000

.......__t 35000 Spent Fuel Assembly Storage 3.7.17 Figure 3.7.17 ASSEMBLY BURNUP VERSUS INITIAL Region Cat decay times from 0 to 20 ****** *****

• ACCEWTABLE Region 4 : .

c * : : E. .. 15 NOT AC EPTABLE or Region :

C/J *** 15000

• rytime. :

____-4_____+_____________*1.5 2.0 2.5 3.0 3.5 4.0 4.5

• 5.0 Initial Enrichment.

weight % 4.80% limiting Decay lime -+-0 years -'-5 years 10 years ___ 15 years ___20 enrichment PALO VERDE UNITS 1.2.3 3.7.17-4 AMENDMENT NO.

AC Sources -Operating 3.8.1 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources -Operating 3.8.1 The following AC electrical sources shall be OPERABLE: Two circuits between the offsite transmission network and the onsite Class IE AC Electrical Power Distribution System; Two diesel generators COGs) each capable of supplying one train of the onsi Class IE AC Electrical Power ibution System; and Automatic load sequencers for Train A and Train B. APPLICABI LITY: MODES 1. 2. 3. and 4. ACTIONS -------------

---

---NOTE-------

LCO 3.0.4.b is not applicable to DGs. CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite circuit inoperable.

A.l AND A.2 AND Perform SR 3.8.1.1 for required OPERABLE offsi circuit. Declare required featureCs) with no offsite power available inoperable when i redundant required feature(s) is inoperable.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> thereafter 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> from discovery of no offsi power to one train concurrent with inoperability of redundant required feature(s) (continued)

PALO VERDE UNITS 3.8.1-1 AMENDMENT NO. +/-+/-+.

3.8.1 AC Sources -Operating ACTIONS CONDITION REQUIRED ACTION TIME A. (continued)

A.3 Restore required offsite circuit to OPERABLE status. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> AND -13 days from discovery of failure to meet LCO B. One DG inoperable.

B.1 AND -B.2 AND-B.3.1 OR-B.3.2 AND-Perform SR 3.8.1.1 for the OPERABLE required offsite circuit(s) . Dec 1 are requ -j red feature(s) supported by the -j noperab 1 e DG inoperable when its redundant required feature(s) is inoperable.

Determine OPERABLE DG is not inoperable due to common cause failure. Perform SR 3.8.1.2 for OPERABLE DG. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND-Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> thereafter 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> from discovery of Conditi on B concurrent with i noperab-Il i ty of redundant required feature(s) 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> (cont-j nued) PALO VERDE UNITS 1,2,3 3.8.1-2 AMENDMENT NO. m, 3.8.1 AC Sources -Operating ACTIONS CONDITION REQU I RED ACTI ON B. (continued)

B.4 Restore DG 10 days to OPERABLE status. AND -13 days from discovery of failure to meet LCO C. Two requi red offsite circuits inoperable.

C.1 AND -C.2 Declare required 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> from feature(s) inoperable discovery of when its redundant Conditi on C required feature(s) concurrent with is inoperable.

inoperabilityof redundant required feature(s)

Restore one required 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> offsite circuit to OPERABLE status.

PALO VERDE UNITS 1.2.3 3.8.1-3 AMENDMENT NO. +/-+/-+.

3.8.1 AC Sources Operating ACTIONS (continued)

COMPLETION TIME REQU I RED ACTI ON CONDITION

---

NOTE-------circuit D. One required offsite Enter applicable Conditions and Required Actions LCD 3.8.9, "Distribution Systems -Operati ng," One DG Condition D is entered with no AC power source to a train. 0.1 Restore required 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> offsite circuits to OPERABLE status. OR 0.2 Restore DG 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> to OPERABLE status. E. Two DGs inoperable.

E.1 Restore one DG to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> OPERABLE status. F. One automatic load F.1 Restore automatic 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> sequencer inoperable.

load sequencer to OPERABLE status. AND F.2 Declare required 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> from feature(s) supported discovery of by the inoperable Conditi on F sequencer inoperable concurrent with when its redundant i noperabil ity of required feature(s) redundant is inoperable.

required feature(s) (cont-j nued) PALO VERDE UNITS 1,2,3 3.8.1 4 AMENDMENT NO. 117 AC Sources -Operating 3.8.1 ACTIONS (continued)

CONDITION G. One or more required offsite circuit(s) do not meet required capability.

REQUIRED ACTION G.l Restore required capability of the offsite circuit(s).

OR--_....

---Enter LCO 3.8.1 Condition A or C for required offsite circuit(s) inoperable.

---

COMPLETION l'1E 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> G.2 Transfer the bus(es) from the offsite circuit(s) to the EDG( s) . 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> H. Required Action and Associated Completion Time of Condition A. B. C. D. E. F. H.l Be in MODE 3. AND-6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> or G not met. H.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> 1. Three or more required AC sources inoperable.

1.1 Enter LCO 3.0.3. Immediately PALO VERDE UNITS 1,2.3 3.8.1-5 AMENDMENT NO. +/-++.

3.8.1 AC Sources -Operating SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each required offsite circuit. 7 days SR 3.8.1. 2 1. --Performance of SR 3.8.1.7 satisfies this SR. 2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. 3 A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met. 4. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error. Verify each DG starts from standby condition and achieves steady state voltage 4000 V and 4377.2 V. and frequency 59.7 Hz and 60.7 Hz. 31 days PALO VERDE UNITS 1.2.3 3.8.1-6 NO. . 158 3.8.1 AC Sources -Operating SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1. 3 SURVEILLANCE

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momenta ry trans i ents outs i de the load range do not invalidate this test. 3. This Surveillance shall be conducted on only one DG at a time. 4. Thi s SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7. Verify each DG is synchronized and loaded, and operates for 60 minutes at a load 4950 kW and 5500 kW. FREQUENCY 31 days SR 3.8.1.4 Verify each day tank contains 550 gal fuel oil (minimum level of 2.75 feet). of 31 days SR 3.8.1. 5 Check for and remove each day tank. accumulated water from 92 days SR 3.8.1. 6 Verify the fuel oil transfer system operates to automatically transfer fuel oil from the storage tank to the day tank. 31 days PALO VERDE UN 1.2,3 3.8.1-7 AMENDMENT NO.

3.8.1 AC Sources Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1. 7

1. All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading. 2. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error. Verify each DG starts from standby 184 days condition and achieves a. In::; 10 seconds, voltage 3740 V and frequency 58.8 Hz; and b. Steady state voltage 4000 V and ::; 4377.2 V. and frequency 59.7 Hz and::; 60.7 Hz. SR 3.8.1.8 This Surveillance shall not normally be performed in MODE 1 or 2. However. this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines safety of the plant is maintained or enhanced.

Verify manual transfer of AC power sources from the normal offsite circuit to each alternate off site circuit. 18 months PALO VERDE UN 1,2.3 3.8.1-8 AMENDMENT NO. 156 3.8.1 AC Sources -Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1. 9 NOTE This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4. However. this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

SR 3.8.1.10 Verify each DG rej a load greater than or equal to its associated single largest post-accident load. and: a. Fo 11 owi ng load rej ecti on. the frequency is 64.5 Hz; b. Within 3 seconds following load rejection.

the voltage is 3740 V and 4580 V; and c. Withi n 3 seconds fo 11 owi ng load rejection.

the frequency is 58.8 Hz and 61.2 Hz.

NOTE If performed with the DG synchronized with offsite power. it shall be performed at a power factor of 0.89. However. if grid conditions do not permit. the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Verify each DG does not trip. and voltage is maintained 6200 V during and following a load rejection of 4950 kW and 5500 kW. 18 months 18 months PALO VERDE UNITS 1.2.3 3.8.1-9 NO. . 167 3.8.1 AC Sources -

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.1.11 --------------NOTE All DG starts may be preceded by an engine prelube period. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Momentary voltage and frequency transients induced by load changes do not invalidate this test. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error. Verify on an actual or simulated loss of ite power signal: De energization of emergency buses: Load shedding from emergency buses: DG auto-starts and: energizes permanently connected loads in 10 seconds, energizes auto-connected emergency loads through automatic sequencer. maintains steady state voltage 4000 V and 4377.2 V, maintains steady state frequency 59.7 Hz and 60.7 Hz, and supplies permanently connected and auto-connected emergency loads for 5 minutes.

18 PALO VERDE UN 3.8.1 10 AMENDMENT NO. 156 3.8.1 AC Sources SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR All DG starts may be preceded by an engine prelube period. This Surveillance shall not normally be performed in MODE 1. 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. The steady state voltage and frequency limi are analyzed values and have not been adjusted for instrument error. Veri fy on an actual or s i mu 1 ated Engi nee red Safety Feature ( F) actuation signal (without a loss of offsite power) each DG auto-starts and: In 10 seconds. achieves voltage 3740 V and frequency 58.8 Hz; Achi eves steady state vo ltage 4000 and 4377.2 V and frequency 59.7 Hz and 60.7 Hz: Operates for 5 minutes on standby (running unloaded); Permanently connected loads remain energized from the offsite power system; and Emergency loads are energized connected through the automatic load sequencer) from the offsite power system.

18 PALO VERDE UNITS 3.8.1-11 NO. 156 3.8.1 AC Sources -

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8 .l.13 Verify each DG automatic trip is bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except: a. Engi ne overspeed;

b. Generator differential current: 18 months c. d. Engine low lube oil pressure; Manual emergency stop trip. and PALO VERDE UNITS 1.2.3 3.8.1 12 AMENDMENT NO. +/-+/-+.

3.B.l AC Sources -

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.B.l.14 -----------NOTES--

---

Momentary transients outside the load range do not invalidate this test. If performed with the DG synchronized with offsite power. it shall be performed at a power factor of 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. All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading. DG loading may include gradual loading as recommended by the manufacturer.

Verify each DG operates for 24 hours1 days <br />0.143 weeks <br />0.0329 months <br />: For 22 hours0.917 days <br />0.131 weeks <br />0.0301 months <br /> 1 oaded 4950 kW and 5500 kW; and For the remai ni ng hours 2) of the t loaded 5775 kW and 6050 kW.

IB PALO VERDE UNITS 3.B.I-13 AMENDMENT NO. +/-+/-+.

3.8.1 AC Sources -Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG. loaded 4950 kW and 5500 kW, has operated 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> or until temperatures have stabilized.

Momentary transients outside of load range do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period. 3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error. Veri fy each DG starts and achi eves a. In 10 seconds, vo ltage 3740 V and frequency 58.8 Hz; and b. Steady state voltage 4000 V and 4377.2 V, and frequency 59.7 Hz and 60.7 Hz. 18 months SR 3.8.1.16 This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4. 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: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsi power; b. Trans rs loads to offsite power source; and c. Returns to ready-to-load operation.

18 months (continued)

PALO VERDE UNITS 1.2.3 3.8.1-14 AMENDMENT NO. 156 3.8.1 AC Sources -Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1. ---------NOTE This Surveillance shall not normally be performed in MODE 1, 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. with a DG operating in mode and connected to its bus. an actual or simulated actuation signal overrides the test mode by: a. Returning DG to ready-to load operation; and b. Automatically energi ng the emergency load from offsite power. 18 months SR 3.8.1.18 This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4. However. this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify interval between each sequenced load block is within +/- 1 second of design interval for each automatic load sequencer.

18 months PALO VERDE UNITS 1.2.3 3.8.1 15 AMENDMENT NO. +/-+/-+.

3.8.1 AC Sources -

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.1.19 ---------------NOTES

-AllDG starts may be preceded by an engine prelube period. This Surveillance shall not normally be performed in MODE 1, 2, 3. or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determ"j nes the safety of the plant is maintained or enhanced. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error. Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: De-energi zati on emergency buses; Load shedd"j ng from emergency buses; DG auto-starts from standby condition and: energizes permanently connected loads in 10 seconds, energizes auto-connected emergency loads through load sequencer, achi eves steady state voltage 4000 V and 4377.2 V, achieves steady state frequency 59.7 Hz and 60.7 Hz. and supplies permanently connected and auto-connected emergency loads for 5 minutes.

18 PALO VERDE UNITS 3.8.1-16 AMENDMENT NO. 156 3.8.1 AC Sources -

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 -----------

---NOTES All DG starts may be preceded by an engine prelube period. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error. Verify. when started simultaneously.

each 10 years DG achieves In::; 10 seconds. voltage ;::: 3740 V and frequency;:::

58.8 Hz; and Steady state voltage;:::

4000 V and ::; 4377.2 V. and frequency;:::

59.7 Hz and::; 60.7 Hz. PALO VERDE UNITS 3.8.1-17 AMENDMENT NO. 156 AC Sources Shutdown 3.8.2 3.8 ECTRICAL POWER SYSTEMS 3.8.2 AC Sources Shutdown 3.8.2 The following AC electrical power sources shall be OPERABLE: One circuit between the offsite transmission network and the onsite Class lE AC ectrical power distribution subsystemCs) required by LCO 3.8.10. "Distribution Systems Shutdown";

and One diesel generator COG) capable of supplying one train of the onsite Class AC electrical power distribution subsystem(s) required by LCO 3.8.10.

MODES 5 and 6. During movement of irradiated fuel assemblies.

ACTIONS ------------------------------NOTE-------------------In MODES 1. 2. 3, and 4. Required Actions A.2.3 and B.3 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsi circuit inoperable.

Enter applicable Conditions and Required Actions of LCO 3.8.10. with one required train de-energized as a result of Condition A. A.l Declare affected required feature(s) with no offsi power available inoperable.

Immediately OR A.2.1 Suspend CORE ALTERATIONS.

Immediately AND (continued)

PALO VERDE UN 1.2.3 NO. 117 AC Sources -Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COI'1PLETION TIME A. (continued)

A.2.2 AND-A.2.3

-A.2.4 Suspend movement of i rradi ated fuel assemblies.

Initiate action to suspend operations involving positive reactivity additions.

Initiate action to restore required offsite power circuit to OPERABLE status. Immediately Immediately Immediately B. One required DG inoperable.

B.l AND -B.2 AND -S.3 AND -B.4 Suspend CORE AL TERATIONS.

Suspend movement of -irradiated fuel assemblies.

Initiate action to suspend operations involving positive reactivity additions.

Initiate action to restore required DG to OPERABLE status. Immediately Immediately Immediately Immediately PALO VERDE UNITS 1,2,3 3.8.2-2 AMENDMENT NO.

3.8.2 AC Sources -Shutdown SURVEILLANCE REQUIREMENTS SR The following SRs are not required to be performed:

SR 3.8.1.3, SR 3.8.1.6, SR 3.8.1.9 through SR 3.8.1.11 , SR 3.8.1.13 through SR 3.8.1.16 , and SR 3.8.1.18. For AC sources required to be OPERABLE, the SRs of Specification 3.8.1. "AC Sources -Operating," except SR 3.8.1.8, SR 3.8.1.12 , SR 3.8.1.17 , SR 3.8.1.19 and SR 3.8.1.20 , are applicable.

In accordance with applicable SRs PALO VERDE UNITS 1,2,3 3.8.2-3 NO.

3.8.3 Diesel Fuel Oil. Lube Oil. and Starting 3.8 ECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil. Lube Oil, and Starting Air LCO The stored diesel fuel oil, lube oil. and starting air subsystem shall be within limits for each required di generator (DG).

When associated DG is required to be OPERABLE.

ACTIONS ------------------------

--NOTE Separate Condi on entry is allowed for each DG. A. CONDITION One or more DGs with fuel level < 80% indicated fuel level and 71% indicated fuel level in storage tank. A.1 REQUIRED ACTION Restore fuel oil 1 eve 1 to withi n 1 imits. COMPLETION TIME 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> B. One or more DGs with lube oil inventory

< 2.5 inches and > 1 inch visible in the sightglass.

B.1 Restore lube oil inventory to within limits. 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> C. One or more DGs with stored fuel oil total particulates not withi n 1 i mits. C.1 Restore fuel oil total particulates to withi n 1 i mits. 7 days (continued)

PALO VERDE UNITS 1.2,3 AMENDMENT NO. 117 Di ese 1 Fuel Oil, Lube Oil. and Start; ng A-j r 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with new fuel oil properties not within limits. 0.1 Restore stored fuel oil properties to withi n 1 i mits. 30 days E. One or more DGs with a required starting air receiver pressure < 230 psig and 185 psig. E.l Restore starting air receiver pressure to 230 pSig. 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> F. Required Action and associated Compl on Time not met. OR-NOTE Should the required starting air receiver pressure momentarily drop to <185 psig while starting the DG on one air receiver only. then entry into Condition F is not required. -One or more DGs with diesel fuel oil. lube oil. or starting air subsystem inoperable for reasons other than Condition A. B. C, 0, or E. F.l Declare associated DG inoperable.

Immediately PALO VERDE UNITS 1.2.3 3.8.3-2 AMENDMENT NO. +/-+/-+.

3.8.3 Diesel Fuel Oil. Lube Oil. and Starting Air SURVEILLANCE REQUIREMENTS SR 3.8.3.1 SURVEILLANCE Verify each fuel oil storage tank contains 80% indicated fuel level. FREQUENCY 31 days SR 3.8.3.2 Verify lubricating oil inventory is 2.5 inches visible in the sightglass.

31 days SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are tested in accordance with. and maintained within the limits of, the Diesel Fuel Oil Testing Program. In accordance with the Diesel Fue 1 Oil Testing Program SR 3.8.3.4 Verify each DG starting air receiver pressure is 230 psig. 31 days SR 3.8.3.5 Check for and each fuel oil remove accumulated water from tank 92 days PALO VERDE UNITS 1,2.3 3.8.3-3 AMENDMENT NO. +/-+/-+,

3.8.4 DC Sources -

3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources Operating LCD 3.8.4 The Train A and Train B DC electrical power subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4. ACTIONS A. B. CONDITION One DC ectrical power subsystem (exclusive of the battery charger) inoperable.

Required Action and associated Completion me of Condition A not met. A.1 B.1 AND-B.2 REQUIRED ACTION Restore DC electrical power subsystem to OPERABLE status. Be in MODE 3. in MODE 5. COlvlPLETION TIME 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> C. D. Required DC electrical power subsystem battery charger inoperable.

Required Action and associated Completion Time of Condition C not met. C.1 AND-C.2 0.1 Verify battery cell parameters meet Table 3.8.6-1 category A 1 i mits Restore DC electrical power subsystem battery charger to OPERABLE status Declare associated battery inoperable.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND-Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> thereafter 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> Immediately PALO VERDE UN 1.2,3 3.8.4 1 AMENDMENT NO.

3.8.4 DC Sources Operating SURVEILLANCE REQUIREMENTS FREQUENCY SURVEILLANCE SR 3.8.4.1 Verify battery terminal on float charge. voltage is V SR SR 3.8.4.2 3.8.4.3 Verify no vi sib 1 e corros i on at battery terminals and connectors.

OR Verify battery connection resistance is 150E-6 ohms for inter-cell connections. 150E-6 ohms for inter rack connections. 150E-6 ohms for inter tier connections.

and 150E-6 ohms for terminal connections.

Verify battery cells. cell plates. and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance.

SR 3.8.4.4 Remove visible terminal corrosion and verify battery cell to cell and terminal connections are clean. and are coated with anti corrosion material.

SR 3.8.4.5 Verify battery connection resistance is 150E 6 ohms for inter-cell connections. 150E-6 ohms for inter-rack connections.

s 150E-6 ohms for inter tier connections.

and s 150E-6 ohms for terminal connections.

7 days 92 days 18 months 18 months 18 months PALO VERDE UNITS 1.2.3 3.8.4-2 AMENDMENT NO. ++/-+

3.8.4 DC Sources -Operating SURVEILLANCE REQUIREMENTS (continued)

FREQUENCY SURVEILLANCE SR 3.8.4.6 ------------

This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4 on the charger credited for OPERABILITY.

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 18 months 400 amps for Batteries A and Band 300 amps for Batteries C and D at 125 V for 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br />. SR 3.8.4.7 ------------NOTES

1. The battery performance discharge test or the modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7. 2. This Surveillance shall not be performed in MODE 1. 2, 3, or 4. Verify battery capacity is adequate to 18 months supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

PALO VERDE UN 1.2,3 3.8.4-3 AMENDMENT NO. ,

3.8.4 DC Sources SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR This Surveillance shall not be performed in MODE 1. 2, 3, or 4. Verify battery capacity is 80% of the rat-j ng when subjected to a performance discharge test or a modified performance discharge test.

60 months AND months when battery shows degradation or has reached 85% of the expected 1 ife with capacity < 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected 1 i fe wi th capacity 100% of manufacturer's rating PALO VERDE UNITS 3.8.4 4 AMENDMENT NO. +/-§e, 158 DC Sources -Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources Shutdown LCO 3.8.5 DC ectrical power subsystem shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.10. "Distribution Systems -Shutdown." APPLICABILITY:

MODES 5 and 6. During movement of irradiated fuel assemblies.

ACTIONS ---------------NOTE--------------------------------In MODES 1. 2. 3, and 4. Required Action A.2.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required DC electrical power subsystems (exclusive of the battery charger) inoperable.

A.1 Declare affected required feature(s) inoperable.

OR A.2.1 Suspend CORE AL TERATIONS.

AND A.2.2 Suspend movement of irradiated fuel assemblies.

AND A.2.3 Initiate action to suspend operations involving positive reactivity additions.

AND Immediately Immediately Immediately Immediately (continued)

PALO VERDE UNI 1.2.3 3.8.5-1 AMENDMENT NO.

DC Sources Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.4 Initiate action to restore required DC electrical power subsystems to OPERABLE status. Immediately B. Required DC ectri ca 1 power subsystem battery charger inoperable.

B.l AND Verify battery cell parameters meet Table 3.8.6-1 category A 1 imi 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND-Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> thereafter B.2 Restore DC electrical power subsystem battery charger to OPERABLE status. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. Required Action and associated Completion Time of Condition B not met. C.1 Declare associated battery inoperable.

Immediately SURVEILLANCE SR FREQUENCY SURVEILLANCE

---

NOTE The following SRs are not required to be performed:

SR 3.8.4.6. SR 3.8.4.7. and SR 3.8.4.8. For DC sources required to be OPERABLE, the In accordance following SRs are applicable:

with applicable SRs SR 3.8.4.1 SR 3.8.4.4 SR 3.8.4.7 SR 3.8.4.2 SR 3.8.4.5 SR 3.8.4.8. SR 3.8.4.3 SR 3.8.4.6 PALO VERDE UNITS 1.2.3 3.8. 2 AMENDMENT NO.

3.8 3.8.6 Battery Cell ICAl POWER SYSTEMS 3.8.6 Battery Cell Parameters lCO 3.8.6 Battery cell parameters for the Train A and Train B batteries shall be within the limi of Table 3.8.6-1. APPLICABILITY:

When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS Sepa Condition entry is allowed for each battery.

PALO VERDE UNITS 1,2,3 3.8.6 1 AMENDMENT NO.

Battery Cell Pa 3.8.6 ACTIONS (continued)

COND ON REQUIRED ACTION COMPLETION ME B. Requi red Acti on and associated Completion Time of Condition A not met. OR One or more batteries with average electrolyte temperature of the representative cells < 60°F. OR One or more batteries with one or more battery cell parameters not within Category C limits. B.1 Declare associated battery inoperable.

Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet 7 days Table 3.8.6-1 Category A limi PALO VERDE UN 1.2.3 3.8.6-2 AMENDMENT NO.

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6 1 Category B limits. 92 days AND Once within 7 days after battery discharge

< 105 V AND Once within 7 days after battery overcharge

> 150 V SR 3.8.6.3 Verify average electrolyte temperature of representative cells is 60°F. 92 days PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO.

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)Battery Surveillance Requirements Electrolyte Level CATEGORY A: LIMITS FOR EACH DESIGNATED PILOT CELL > Minimum level indication mark. and ::; inch above maximum i level indication mark Ca ) CATEGORY B: LIMITS FOR EACH CONNECTED CELL > Minimum level indication mark. and ::; inch above maximum level indication mark Ca ) CATEGORY C: ALLOWABLE LIMITS FOR EACH CONNECTED Above top of plates. and not overflowing Float Voltage 2.13 V 2.13 VCd) > 2.07 V Specific 1. 200 1.195 Not more than Gravi tyCb)(c) AND-Average of all connected cells 1. 205 0.020 below average connected 1s -Average of all connected cells 1.195 It is acceptable for the ectro1yte level to temporarily increase above the specified maximum during equalizing charges provided it is not overflowing. Corrected for electrolyte temperature and level. Level correction is not required.

however, when battery charging is < 2 amps when on float charge. A battery charging current of < 2 amps when on float charge is acceptable for meeting specific gravity limits fo11ow'ing a battery recharge, for a maximum of 7 days. When charging current is used to satisfy speci c gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance. Corrected for average electrolyte temperature. VERDE UNITS 1,2.3 3.8.6-4 AMENDMENT NO. +/-+/-+ 158 Inverters

-Operating 3.8.7 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters

-Operating LCO 3.8.7 required Train A and Train B inverters shall be OPERABLE.

---

NOTE ------One inverter may disconnected from its associated DC bus for 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> to perform an equalizing charge on its associated battery. provlded: The associated AC vital instrument bus is energized from Class 1E constant voltage source regulator:

and All other AC vital instrument buses are energized from their assoclated OPERABLE inverters.

APPLICABILITY:

MODES 1. 2. 3. and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required inverter inoperable.

A.1 Enter applicable Condit ions and Required Actions LCO 3.8.9, "Distribution Systems Operating" wlth any vital -j nstrument bus de-energized.

tore inverter to OPERABLE 7 days inued) PALO VERDE UNITS 3.8.7-1 AMENDMENT NO. +/-++

Inverters

-Operating 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> B.l Be in MODE 3. associated Compl Time not met. on AND B.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, 7 days and alignment to required AC vital instrument buses. PALO VERDE UNITS 1,2,3 3.8.7-2 AMENDMENT NO.

Inverters Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters Shutdown LCO 3.8.8 Required inverter(s) shall be OPERABLE to support the onsite Class 1E AC vital instrument bus electrical power distribution subsystem(s) required by LCO 3.8.10,"Distribution Systems -Shutdown." APPLICABILITY:

MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS ----------

---

NOTE-In MODES 1. 2, 3, and 4, Required Action A.2.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required inverters inoperable.

A.1 Declare affected required feature(s) inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND A.2.2 Suspend movement of irradiated fuel assemblies.

AND A.2.3 Ini ate action to suspend operations involving positive reactivity additions.

Immediately Immediately Immediately Immediately (continued)

PALO VERDE UNITS 1.2.3 3.8.8-1 AMENDMENT NO.

Inverters

-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.4 Initiate action restore required inverters to status. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, 7 days and alignments to required AC vital instrument buses. PALO VERDE UNITS 1,2,3 3.8.8-2 AMENDMENT NO.

Distribution Systems Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distr-ibution Systems -Operat-ing LCO 3.8.9 Train A and Train B AC, DC, and AC vital instrument bus e 1 ectri ca 1 power di str-i buti on subsystems sha 11 be OPERABLE.

APPLICABILITY.

MODES 1, 2. 3. and 4. ACTIONS CONDITION A. One AC electrical power distribution subsystem inoperable.

A.1 REQUI ACTION Restore AC electrical power distribution subsystem to OPERABLE status. COMPLETION TIME 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> AND-16 hours0.667 days <br />0.0952 weeks <br />0.0219 months <br /> from discovery of failure to LCO B. One AC vi 1 instrument bus electrical power distribution subsystem inoperable.

B.1 Restore AC vital instrument bus electrical power distribution subsystem to OPERABLE status. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> AND -16 hours0.667 days <br />0.0952 weeks <br />0.0219 months <br /> from di scovery of failure to LCO PALO VERDE UN 1.2.3 3.8.9-1 AMENDMENT NO.

Distribution Systems -Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION TIME C. One DC electrical power distribution subsystems inoperable.

C.l Restore DC electrical power distribution subsystem to OPERABLE status. 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> AND-16 hours0.667 days <br />0.0952 weeks <br />0.0219 months <br /> from discovery of failure to meet LCD D. Required Action and associated Completion Time not met. 0.1 AND-Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> 0.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> E. Two or more inoperable distribution subsystems that result in a loss of safety function.

E.l Enter LCD 3.0.3. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to required AC, DC. and AC vital instrument bus electrical power distribution subsystems.

7 days PALO VERDE UNITS 1.2.3 3.8.9-2 AMENDMENT NO.

Distribution Systems -Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems -Shutdown LCO 3.8.10 The necessary portion of AC. DC. and AC vital electrical power distribution subsystems shall to support equipment required to be OPERABLE.

instrument bus be OPERABLE APPLICABILITY:

MODES 5 and 6. During movement of irradiated fuel assemblies.

ACTIONS --In MODES 1. 2. 3. and 4. Required Action A.2.3 is not CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required AC. DC. or AC vital instrument bus electrical power distribution subsystems inoperable.

A.1 OR A.2.1 AND A.2.2 AND A.2.3 AND Declare associated supported required ture(s)inoperable.

Suspend CORE AL TERATIONS.

Suspend movement of i rradi ated fuel assemblies.

Initiate action to suspend operations involving positive reactivity additions.

Immediately Immediately Immediately Immediately (continued)

PALO VERDE UNITS 1,2,3 3.8.10-1 AMENDMENT NO.

Distribution Systems -Shutdown 3.8.10 ACTIONS COND ION REQUIRED ACTION A. (conti nued) A.2.4 Initiate actions to AND restore required AC, DC. and AC vital instrument bus ectrical power distribution subsystems to OPERABLE status. A.2.5 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.

Immediately Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required AC. DC. and AC vital -instrument bus electrical power distribution subsystems.

7 days PALO VERDE UNITS 1.2.3 3.8.10-2 AMENDMENT NO.

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR. APPLI CAB I LI TY : MODE 6. ACTIONS CONDITION REQU I RED ACTI ON TIME A. Boron concentration not within limit. A.1 AND A.2 AND A.3 Suspend CORE AL TERATIONS.

Suspend positive reactivity additions.

Initi action to restore boron concentration to withi n 1 imit. Immediately Immediately Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> limit specified in the COLR. PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO.

Nuclear Instrumentation 3.9.2 3.9 REFUELING 3.9.2 Nuclear LCD 3.9.2 Two startup range monitors (SRMs) shall be APPLICABILITY:

MODE 6. ACTIONS Enter applicable Conditions and Required Actions of LCD 3.3.12. "Boron Dilution Alarm System (BOAS)" for BOAS made inoperable by SRMs. CONDITION REQUIRED ACTION COMPLETION A. One required SRM inoperable.

A.I AND A.2 Suspend CORE AL TERATIONS.

Suspend positive reactivity additions.

Immediately Immediately B. Two requi red inoperable.

B.1 Initiate action to restore one SRM to OPERABLE status. Immediately PALO VERDE UNITS 1,2.3 3.9.2 1 NO. W 138 Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. hours SR 3.9.2.2 Neutron detectors are excluded from CHANNEL CALI BRAT ION . Perform CHANNEL CALIBRATION.

18 months PALO VERDE UNITS 1.2.3 3.9.2-2 AMENDMENT NO.

Containment Penetrations 3.9.3 REFUELING OPERATIONS 3.9.3 Containment Penetrations LCO The containment penetrations shall be in the following status: The equipment hatch closed and held in place by four bolts, or if open, capable of being closed: One door in each air lock is capable of being closed; and Each penetration providing direct access from the containment atmosphere to the outside atmosphere either: closed by a manual or automatic isolation valve, blind flange, or equivalent.

or capable of be'j ng closed by an OPERABLE Contai nment Purge and Exhaust Is01 on System. ------------NOTE--Penetration ow path(s) providing di access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

During CORE ALTERATIONS.

During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment penetrations not in required status. A.l AND Suspend CORE ALTERATIONS.

Immediately A.2 Suspend movement of i rradi ated fuel assemblies within containment.

Immediately PALO VERDE UNITS 3.9.3 1 AMENDMENT NO. +/-4J Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the required status. 7 days SR 3.9.3.2 Verify each required containment purge and exhaust valve actu to the isolation position on an actual or simulated actuation gnal. 18 months SR 3.9.3.3 Verify the capability to close the equipment hatch. if open 7 days PALO VERDE UNITS 1.2.3 3.9.3 2 AMENDMENT NO.

SOC and Coolant Circulation -High Water 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Shutdown Cooling (SOC) and Coolant Circulation High Water Level LCD 3.9.4 One SOC loop shall be OPERABLE and in operation.

---

NOTE------

---

The required SOC loop may be removed from 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.

APPLICABILITY: 6 with the water level 23 ft above the top of reactor vessel ange. ACTIONS CONDITION REQUIRED ACTION TIfvlE A. SOC loop requirements not met. A.1 Suspend operations involving a reduction in reactor coolant boron concentration.

Immediately AND A.2 Suspend loading irradiated fuel assemblies in the core. Immediately AND A.3 Initiate action to satisfy SOC loop requirements.

Immediately AND (continued)

PALO VERDE UNITS 1,2,3 3.9.4 AMENDMENT NO.

SOC and Coolant Circulation -High Water Level 3.9.4 CONDITION REQU IRED ACTI ON COMPLETION TIME A. (continued)

A.4 Close all containment penetrations providing direct access from containment atmosphere to outside atmosphere.

4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> SURVEILLANCE FREQUENCY SURVEI LLANCE SR 3.9.4.1 Verify one SOC loop is operable and in 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> operation.

PALO VERDE UNITS 1,2,3 3.9.4-2 AMENDMENT NO.

SOC and Coolant Circulation Low Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Shutdown Cooling (SOC) and Coolant Circulation

-Low Water Level LCO Two SOC loops shall be OPERABLE, and one SOC loop shall be in operation.

---

NOTES The required SOC loop may be removed from 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. One required SOC loop may be inoperable for up to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for surveillance testing. provided the other SOC loop is OPERABLE and in operation.

APPLICABILITY: 6 with the water level < 23 ft above the top of reactor vessel fl ange. ACTIONS REQU I RED ACTI A. One SOC loop inoperable.

A.l OR A.2 I ni ate action to restore SOC to OPERABLE status. Initiate action to establish 23 ft of water above the top of reactor fl ange. COMPLETION Immediately Immedi y PALO VERDE UNITS 3.9.5-1 AMENDMENT NO.

SOC and Coolant Circulation

-Low Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION B. No SOC loop OPERABLE or in operation.

B.1 AND B.2 AND B.3 Suspend operations involving a reduction in reactor coolant boron concentration.

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

Close all containment penetrations providing direct access from containment atmosphere to outside atmosphere.

Immediately Immediately 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify required SOC loops are OPERABLE and one SOC loop is in operation.

12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required SOC pump that is not in operation.

7 days PALO VERDE UN 1,2,3 3.9.5-2 AMENDMENT NO.

Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Water Fuel Assemblies LCO Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.

During movement of fuel assemblies within containment when ther the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated.

ACTIONS COND ON REQUIRED ACTION COMPLETION TIME A, Refuel i ng water 1 eve 1 not within limit. A, 1 Suspend movement of fuel assemblies within containment.

Immediately SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling water level is 23 ft 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> above the top of reactor vessel flange. PALO VERDE UN 1.2,3 AMENDMENT NO.

Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Water Level-CEAs LCD 3.9.7 Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel. APPLICABILITY:

During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated.

CONDITION REQUIRED COMPLETION TIME A Refueling water level not within limit. A.1 Suspend movement of CEAs within the reactor vessel. Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling water level is 23 ft 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> above the top of irradiated fuel assemblies seated within the reactor vessel. PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO.

4.0 Design 4.0 DESIGN 4.1 Site Location The Palo Verde Nuclear Generating Station is located in Maricopa County.Arizona. approximately 50 miles west of the Phoenix metropolitan area. The site is comprised of approximately 4.050 acres. Site elevations range from 890 feet above mean sea level at the southern boundary to 1,030 feet above mean sea level at the northern boundary.

The minimum distance from a containment building to the exclusion area boundary is 871 meters. 4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 241 fuel assemblies.

Each assembly shall consist of a matrix of Zircaloy or ZIRLO fuel rods with an ini al composition of natural or slightly enriched uranium dioxide CU0 2) as fuel material.

Limited substitutions of zirconium alloy or sta-inless 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. Other cladding material may be used with an approved exemption.

4.2.2 Element ies The reactor core shall contain 76 full strength and 13 part strength control element assemblies (CEAs). The control section for the full strength CEAs shall be either boron carbide with Alloy 625 cladding.

or a combination of silver indium-cadmium and boron carbide with Alloy 625 cladding.

The control section for the part strength CEAs shall be solid Alloy 625 slugs with Alloy 625 cladding. (cont-i nued) PALO VERDE UNI 1.2,3 4.0-1 AMENDMENT NO.

Design Features 4.0 DESIGN FEATURES (continued) Fuel Storage 4.3.1 Criticality The spent fuel storage racks are designed and shall be maintained with: Fuel assemblies having a maximum radially averaged U-235 enrichment of 4.80 weight percent; keff < 1.0 if fully flooded with unborated water. which includes an allowance for biases and uncertainties as described in Section 9.1 of the UFSAR; keff 0.95 if fully flooded with water borated to 900 ppm. which includes an allowance for biases and uncertainties as described in Section 9.1 of the UFSAR. A nominal 9.5 inch center-to-center distance between adjacent storage cell locations. Region 1: Fuel shall be stored in a checkerboard Ctwo-out-of-four) storage pattern. Fuel that qualifies to be stored in Regions 1. 2. 3. or 4 in accordance with Figures 3.7.17 1. 3.7.17-2.

or 3.7.17-3.

may be stored in Region 1. Region 2: Fuel shall be stored in a repeating 3-by-4 storage pattern in which Region 2 (two-out-of-twelve) assemblies and Region 4 (ten-out-of-twelve) assemblies are mixed as shown in Section 9.1 of the UFSAR. Only fuel that qualifies to be stored in Regions 2. 3, or 4. in accordance with gures 3.7.17-1. 3.7.17-2.

or 3.7.17 3. may be stored in Region 2. Region 3: Fuel shall be stored in a four four storage pattern. Only fuel that qualifies to be stored in Regions 3 or 4. in accordance with Figures 3.7.17-2 or 3.7.17 . may be stored in Region 3. (continued)

PALO VERDE UNITS 4.0-2 AMENDMENT NO. 125 Design Features 4.0 IGN FEATURES (continued) Region 4: Fuel shall be stored in a repeating by-4 storage pattern in which Region 2 (two out of-twelve) assemblies and Region 4 (ten-out-of-twelve) assemblies are mixed as shown in Section 9.1 of the UFSAR. Only fuel that qualifies to be stored in Region 4 in accordance with Figure 3.7.17-3 shall be stored in Region 4. The new fuel storage racks are designed and shall be maintained with: Fuel assemblies having a maximum radially averaged U-enrichment of 4.80 weight percent; S 0.95 if fully flooded with unborated water. which includes an allowance for biases and uncertainties as described in Section 9.1 of the UFSAR; c. S 0.98 if moderated by aqueous foam. which includes an allowance for biases and uncertainties as described in Section 9.1 the UFSAR; and A nominal 17 inch center to center distance between fuel assemblies placed in the storage racks. 4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 137 feet -6 inches. 4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 1329 fuel assemblies.

PALO VERDE UNITS 4.0 3 AMENDMENT NO. +/-+/-+.

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility The Department Leader. Operations shall be respons-ible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence. The Department Leader, Operations or his deSignee shall approve.prior to implementation, each proposed test, experiment or modi cation to systems or equipment that affect nuclear safety. The Control Room Supervisor (CRS) shall be responsible for the control room command function.

During any absence the CRS from the control room while the unit is in MODE 1, 2. 3. or 4. an individual with an active Senior Reactor Operator (SRO) license shall be deSignated to assume the control room command function.

During any absence of the CRS from the control room while the unit is in MODE 5 or 6. an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

PALO VERDE UNITS 5.1 1 AMENDMENT NO. ++/-+

Organization 5,2 5,0 ADMINISTRATI CONTROLS 5,2 Organization 5,2,1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respecti y. The onsi and offsite organizations shall include the positions activities affecting safety of the nuclear power plant. Lines of authority.

responsibility.

and communication shall be defined and established throughout highest management levels. intermediate levels. and all operating organization positions.

These relationships shall be documented and updated, as appropriate, in organization charts. functional descriptlons of departmental responsibilities and relationships.

and job descriptions for key personnel positions, or in equivalent forms 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 UFSAR: 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; A specified corporate officer shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed ensure acceptable performance the staff in operating, maintaini . and providing technical support the plant to ensure nuc ear safety: and The indlvlduals who traln the operating staff, carry out health physics, or perform quallty assurance functions may report to the appropriate onsite manager: however. these individuals shall have sufficient organi onal freedom to ensure their independence from operating pressures.

The unit staff organization shall include the following: A non licensed operator shall be asslgned to each reactor containing fuel and an additional non licensed operator (continued)

PALO VERDE UNI 5,2 1 AMENDMENT NO. 183 5.2.2 Organization 5.2 Organization 5.2.2 Unit Staff (continued) shall be assigned for each control room from which a reactor is operating in MODES 1, 2. 3, or 4. Shift crew composition shall meet the requirements pulated herein and in 10 CFR 50.54(m).

Shi crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.e for a period of not to exceed 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> in order to accommodate unexpected absence of on-duty shi crew members provided immediate action is taken to restore the shift crew composi on to within the minimum requirements. A Radiation Protection Technician shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br />. in order to provide for unexpected absence. provided immediate action is taken to fill the required position. The Operations Department Leader or Operations Supervisor shall hold an SRO license. The Shi Technical Advisor (STA) shall provide advisory technical support to the Shift Manager in the areas of thermal hydrauliCS, reactor engineering, and plant analysis with regard to the safe operation of the unit. In addition.

the STA shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift. PALO VERDE UNITS 5.2-2 AMENDMENT NO. 175 Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Quali cations Each member of the unit staff with the exception of operator license applicants, shall meet or exceed the minimum quali cations of Regulatory Guide 1.8, September 1975 and ANSI/ANS 3.1 1978, except the Director, Site Radiation Protection shall or exceed the qualification of Regulatory Guide 1.8. September 1975. and the Shift Technical Advisor shall have a bachelor's degree or equivalent in a scientific or engineering discipline with specific training in plant design and plant operating characteristics.

including transients and accidents. The education and experience eligibility requirements for operator license applicants, and changes thereto, shall be those previously reviewed and approved by the NRC. specifically those referenced in letter 102-04930-GRO/TNW/RJR, dated April 25. 2003. For the purpose of 10 CFR 55.4. a licensed senior reactor operation (SRO) and a licensed reactor operator (RO) are those individuals who, in addition to meeting the requirements of 5.3.2. perform the functions described in 10 CFR 50.54(m).

PALO VERDE UNITS 5.3 1 NO.

148

Programs and Manuals 5.5 ADMINISTRATIVE CONTROLS Programs and Manuals The following programs shall be established, implemented.

and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM) The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents.

in the calculation of gaseous and liquid uent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and The aDCM shall also contain the radioactive uent controls and radiological environmental monitoring activities and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Reports required by Specification 5.6.2 and Specification 5.6.3. Licensee initiated changes to the ODCM: Shall be documented and records of reviews performed shall be retained.

This documentation shall contain: Sufficient information to support the change(s)together with the appropriate analyses or evaluations justifying the change(s), A determination that the changeCs) 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 Director.

Radiation Protection; and c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive uent Release Report for the period of the report in which any change in the ODCM was made. change shall be identified by markings in the margin of (continued)

PALO VERDE UNIT 5.5-1 AMENDMENT NO. 146 Programs and Manuals 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued) the affected pages, clearly indicating the area of the page that was changed. and shall indicate the date (i .e .. month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment 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 recirculation portion of the high pressure injection system, the shutdown cooling portion of the low pressure safety injection system, the post-accident sampling subsystem of the reactor coolant sampling system (until such time as a modification eliminates the PASS penetration as a potential leakage path), the containment spray system, and the pos accident containment atmosphere sampling piping of the hydrogen monitoring subsystem (until such time as a modification eliminates the PASS penetration as a potential leakage path). The program shall include the following: Preventive maintenance and periodic visual inspection requirements:

and Integrated leak test requirements for each system at refueling cycle intervals or less. 5.5.3 Deleted PALO VERDE UNIT 5.5 2 AMENDMENT NO. . 136 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable.

The program shall be contained in the ODCM, sh 1 be imp 1 emented by procedures, and shall -j nc 1 ude remedi a 1 act; ons to be taken whenever the program limits are exceeded.

The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM; b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to 10 times the concentration values in Appendix S, Table 2, Column 2 to 10 CFR 20.1001-20.2402;

c. Monitoring, sampling.

and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM; d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50. Appendix I; e. Determination of cumulative and projected 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; 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 re 1 eases of radi oacti vity when the projected doses -j n 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; PALO VERDE UNITS 1.2.3 5.5-3 NO. W 120 5.5 Programs and 5.5 Programs and Radioactive Effluent Controls Program (continued)

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary;

1. For noble gases: less than or equal to a dose rate of 500 mrems/yr to the total body and less than or equal to a dose rate of 3000 mrems/yr to the skin. and 2. For iodine-131, iodine-133.

tritium. and for all radionuclides in particulate form with half-lives greater than 8 days: less than or equal to a dose rate of 1500 mrems/yr to any organ; h. Limitations on the annual and quarterly air doses resulting from gases released in gaseous effluents from each unit to areas beyond the site boundary.

conforming to 10 CFR 50. Appendix I; i . Limitations on the annual and quarterly doses to a member of the from iodine 131. iodine-133.

tritium. and all radionuclides in particulate form with half lives> 8 days in effluents released from each unit to areas beyond the site boundary, conforming to 10 C 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. Component Cyclic or Transient Limit This program provides controls to track the UFSAR Section 3.9.1.1 cyclic transient occurrences to ensure that components are maintained within the design limits. Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in Qre stressed concrete containments.

including effectiveness of its corrosion protection medium, to ensure structural integrity.

The program shall 'include baseline measurements prior to initial operations.

The Tendon Surveillance Program, inspection frequencies.

and acceptance criteria shall be in accordance with ASME Code Section XI.

IWL of the ASME Boiler and Pressure Vessel Code and addenda as required by 10 CFR 50.55a, except where an exemption or relief has been authorized by the NRC. The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies. (continued)

PALO VERDE UNITS 5.5-4 AMENDMENT NO.

5.5 Programs and Manuals 5.5 Programs and Manuals 5.5.7 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendations of regulatory position c.4.b of Regulatory Guide 1.14. Revision D. October 1971, 5,5.8 Inservice Testing Program This program provides controls for lnservice ting of ASME Code Class I. 2. and 3 components.

The program shall include the fo 11 owi ng Testing frequencies applicable to the ASME Code for Operatlon and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows: ASME Code applicable Addenda termi no logy 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 Quarter'y 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 At least once per 366 days Blennially or every 2 years At least once per 731 days b. The provisions of SR 3.0 2 are appl cable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities:

c, The provisions of SR 3.0.3 are applicable to inservice ting activities; and Nothing in the ASME OM Code shall be construed to supersede the requlrements of any TS, (continued)

PALO VERDE UNITS 5.5-5 NO, m 184 Programs Manuals 5.5 5.5 Programs and Manuals (continued) Steam Generator (SG) Program A Steam Generator (SG) Program shall be established and implemented to ensure that SG tube integrity is maintained.

In addition.

the Steam Generator Program shall include the following provisions:

a. Provisions for condition monitoring assessments.

Condition 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 condi on 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 cri ria 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 LEAKAGE. 1. Structural integrity performance criterion:

All in service tubes shall retain structural integrity over the full range of normal operating conditions (including startup. operation in the power range. hot standby. and cool down and all anticipated transients included in the design specification) and design basis accidents.

This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation 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 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 secondary accident induced leakage rate for any design basis accident.

other than a SG tube rupture. (continued)

PALO VERDE UNITS 5.5-6 AMENDMENT NO. 161 5.5 Programs and Manuals 5.5 Programs and Manuals (continued) Steam Generator (SG) Program (continued) shall not exceed the leakage ra assumed in the accident analysis in terms of total leakage rate r all SGs and leakage rate an individual SG. Leakage is not to exceed 0.5 gpm per SG and 1 gpm through both SGs. 3, The operational LEAKAGE performance criterion is specified in LCD 34.14. "RCS Operational LEAKAGE," c. Provisions SG tube repair criteria.

Tubes found by lnservice lnspection to contain flaws with a depth equal to or exceeding 40% the nominal tube wall thickness shall be plugged. d. Provlsions 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 ective of detecting flaws 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 at the tube inl to the tube tubesheet weld at tube outl . and that may satisfy the applicable tube 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 low. the inspection scope.inspection methods. and inspection intervals shall be such as to ensure that SG integrity is maintained until the next SG inspection.

An assessment of degradation shall be performed determlne the type and location of flaws to which the tubes may be susceptlble and. based on this assessment.

to determlne which inspection methods need to be employed and at what locatlons.

1. Inspect 100% of tubes in each SG during the first refueling outage following SG replacement.

2. Inspect 100% of the tubes at sequential periods of 144. 108. 72. and. thereafter.

60 effective full power months. fi sequential period shall be considered to begin after the first inservice inspection of the SGs. In additlon.

inspect of the tubes by the refueling outage nearest the mldpoint of the period and the remaining 50% by the refueling outage nearest the end the period. No SG shall operate more than effective full power months or three refueling outages (whichever is less) without belng inspected. (continued)

PALO VERDE UNITS 5.5 7 A,MENDMENT NO. M.

5.5 Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Program (continued)

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less) If definitive information, such as from examination of a pulled tube, diagnostic destructive testing, or engineering evaluation indlcates that a crack-like indication is not associated with a crack(s).

then the indication need not be treated as a crack e. Provisions for monltoring operational primary to secondary LEAKAGE. (continued)

PALO VERDE UNITS 1,2,3 5.5-8 NO. +/-hl, 179 Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.10 Secondary Water Chemistry Program program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking.

The program shall include: Identification of a sampling schedule for the critical variables and control points for these variables; Identification of the procedures used to measure the values of the critical variables; Identification of process sampling pOints which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage; Procedures for the recording and management of data; Procedures defining corrective actions for all off control point chemistry conditions; and A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events. which is required to initiate corrective action. 5.5.11 Ventilation Filter Testing Program (VFTP) A program shall be established to implement the following required testing of Engineered Safety Feature CESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52. Revision 2, and in accordance with Regulatory Guide 1.52, Revision 2 and ANSI N510-1980 at the system flowrate specifi +/- 10%. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass 1.0 %when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1980.

at the system flowrate specified as follows 10%: (continued)

PALO VERDE UNI 5.5-9 AMENDMENT NO. 161 Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.11 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation owrate Control Room Essential 28, 600 System (CREFS) Engineered Safety Feature 6.000 CFM Room Exhaust Air Cleanup System (PREACS) Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass 1.0 %when tested in accordance with Regulatory Guide 1.52, Revision 2. and ANSI N510-1980 at the system flowrate specified as follows +/- 10%: ESF Ventilation Flowrate 28.600 CFM ESF 6,000 CFM Demonstrate for each of the ESF systems that a charcoal adsorber sample, when obtained in accordance with the application of Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978. as described in Section 1.8 of the UFSAR. shows the methyl iodide penetration less than or equal to the v ue specified below. when tested in accordance with ASTM 03803 1989. at a temperature of 30°C and to the relative humidity specified as follows: ESF Ventil ati on System Penetration RH 2.5% 70% ESF 2.5% 70%

PALO VERDE UNITS 5.5-10 AMENDMENT NO. 161 Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.11 Ventilation Filter Testing Program (VFTP) For each of the ESF systems. demonstrate the pressure drop across the combined HEPA filters. the prefilters.

and the charcoal adsorbers is less than or equal to the value specified below when tested in accordance with Regulatory Guide 1.52. Revision 2. and ANSI N510-1980 at the system flowrate specified as follows +/- 10%: ESF Ventilation System Delta P Flowrate CREFS 4.8 inches water gauge 28.600 CFM PREACS 5.2 inches water gauge 6,000 CFM e. Demonstrate that the heaters for each of the systems dissipate the following specified value when tested accordance with ANSI N510-1980:

ESF Ventilation Wattage > 19 kW The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides control 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 outdoor liquid storage tanks. The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11 5. "Postulated Radioactive Release due to Waste Gas System Leak or Failure".

The liquid radwaste quantities shall be determined in accordance with Standard Review Plan. Section .7.3. "Postulated Radioactive Release due to Tank Failures".

PALO VERDE UNITS 5.5 11 AMENDMENT NO.

Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

The program shall include: 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 exp los ion) : A surveillance program to ensure that the quantity of radioactivity contained in each gas storage tank is less the amount that would result in a whole body exposure of ;::: 0.5 rem to any i ndi vi dua 1 in an unrestri cted area, -j n the event of an uncontrolled release of the tanks' contents; and c. A survei 11 ance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by l-j ners, di kes. 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 would result in concentrations less than the limits of 10 CFR Part 20. Appendix B, Table 2. Column 2. at the nearest potable water supply and the nearest surface water supply in an unrestricted area. in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

5.5.13 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of new fuel oil and stored fuel oil shall be established.

The program shall include sampling and testing requirements.

and acceptance criteria.

all in accordance with applicable ASTM Standards as renced in the UFSAR. The purpose of the program is to establish the following: (continued)

PALO VERDE UNITS 5.5-12 NO. 161 Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.13 Diesel Fuel Oil Testing Program (continued) Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has: An API gravity or an absolute specific gravity within 1 i mi A flash point and kinematic viscosity within limits for ASTM 2D fuel oil. and Water and sediment within limits when tested in accordance with ASTM D1796; Other properties for ASTM 2D fuel oil are within limits within 31 days following sampling and addition to storage tanks; and particulate concentration of the stored fuel oil is 10 mg/l when tested every 92 days in accordance with ASTM 0-2276. Method A-2 or A-3. 5.5.14 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the foll owi ng: A change in the TS incorporated in the license; or A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR. (continued)

PALO VERDE UNITS 5.5-13 AMENDMENT NO. +/-d+. 161 Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.14 Technical Specifications (TS) Bases Control Program (continued) Proposed changes that meet the criteria of Specification 5.5.14b above shall be reviewed and approved by the NRC prior to implementation.

Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.15 Safety Function Determination Program (SFDP) This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCD 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCD 3.0.6. The SFDP shall contain the following: 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; Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and Other appropriate limitations and remedial or compensatory actions. A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power. or no concurrent loss of onsite diesel generator(s).

a safety function assumed in the accident analysis cannot be performed.

For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and: A required system redundant to system(s) supported by the inoperable support system is also inoperable; or (continued)

PALO VERDE UNITS 5.5-14 AtvlENDMENT NO W, Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.15 Safety Function Determination Program (continued) A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or A required system redundant to support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this progralll, the appropriate Conditions and Required Actions of the LCO in the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system. 5.5.16 Containment Leakage Rate Testing Program A progralll 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 the guidelines contained in Regulatory Guide 1.163, Based Containment Leak-Test Program," dated September.

1995. as modified by the following exceptions: The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50. Appendix J. Option B testing. will be performed in accordance with the requirements of and frequency specified by ASME Code Section XI, Subsection IWL, except where relief has been authorized by the NRC. The containment concrete visual examination may be performed during either power operation, e.g., perforilled concurrently with other containment inspection-related activities such as tendon testing. or during a maintenance/refueling outage. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR 50. Appendix J. Option B testing. will be performed in accordance with the requirements of and frequency specified by ASME Code Section XI, Subsection IWE, except where reli has been authorized by the NRC. (continued)

PALO VERDE UN 1. 2 AND 3 AMENDMENT NO. ,

Programs and Manuals 5.5 Programs and Manuals (continued) 5.5.16 Containment Leakage Rate Testing Program (continued)

3. The first Type A test performed a the Unit 1 November 1999 Type A test shall be prior to November 4. 2014. The first Type A test performed after the Unit 2 November 2000 Type A test shall be prior to November 2. 20 The first Type A test performed after the Unit 3 April 2000 Type A test shall be pri or to April ,2015. b. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 52.0 pSig for Unit 1 through operating cycle and Unit 3 through operating cycle 13. and 58.0 psig for Unit 1 after operating cycle 12. Unit 2. and Unit 3 after operating cycle 13. The containment design pressure is 60 psig. The maximum allowable containment leakage rate. La, at P a , shall be 0.1 %of containment air weight per day. Leakage Rate acceptance criteria are: Containment leakage rate acceptance criterion is S 1.0 La. During the first unit startup following testing in accordance with this program. the leakage rate acceptance are 0.60 La for the Type Band C and $ 0.75 La for A Ai r lock ng acceptance criteria are: a) Overall air lock leakage rate is $ 0.05 La when tested at ;:::: Pa. b) For each door. leakage rate is $ 0.01 La when pressuri to 14.5 psig. The provisions of SR 3.0.2 do not apply to the test frequencies in the Containment kage Rate Testing Program. f. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program. (cont'j nued) PALO VERDE UNITS 1,2,3 5.5-16 AMENDMENT NO. +/-++/-, 176 Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 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 Essential Flltration System (CREFS), CRE occupants can control the reactor safely under normal conditions and maintain it in a s condition following a radiological event, hazardous chemical release, or a smoke challenge.

The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess 5 rem whole body or its equivalent to any part of the body for the duration of the accident.

The program shall include the following elements: The definition of the CRE and the CRE boundary. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance. Requirements for ei) determining the unfiltered air inleakage past the CRE boundary in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003. and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197. Revision O. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph

c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. 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.

PALO VERDE UNITS 1,2,3 AMENDMENT NO.

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The fo 11 owi ng reports shall be submitted in accordance wi th 10 CFR 50.4. 5.6.1 Deleted 5.6.2 Annual Radiological Environmental Operating Report ----------

---

NOTE -----------A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station. The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C. (continued)

PALO VERDE UNITS 1. 2,3 5.6-1 AMENDMENT NO. 154 Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.2 Annual Radiological Environmental Operating Report The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in the format of the table in the Radiological Assessment Branch Technical Position.

Revision 1, November 1979. In the event that some individual results are not available for inclusion with the report. the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

5.6.3 Radioactive Effluent Release Report ---------------------NOTE

---

A single submittal may be made for a multiple unit station. The submittal should combine sections to all units at the station; however. for units with separate radwaste system. the submittal shall specify the releases of radioactive material from each unit. The Radioactive Effluent Release Report covering the operation of the unit shall be submitted in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous uents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50. Appendix I.Section IV.B.l. 5.6.4 Deleted (cont'j PALO VERDE lINIT 1 AMENDMENT NO. 154 PALO VERDE UNITS 2,3 5.6-2 AMENDMENT NO. 154 Reporting Requirements 5.6 Reporting Requirements (continued) 5.6.5 CORE OPERATING LIMITS REPORT (COLR) Core opera ng limits shall be established prior to reload cycle, or prior to any remaining portion of a reload cycle. and shall be documented in the COLR for the fo 11 owi ng: Shutdown Margin -Reactor Trip Breakers Open for Speci cation 3.1.1. Shutdown Margin Reactor Trip Breakers Closed for Specification 3 1.2. Modera Temperature Coefficient BOL and EOL limi for Specification 3,1.4. Boron Dilution Alarm System for Specification 3,3.12. CEA Alignment for Speci cation 3.1.5. Regul ng CEA Insertion Limits for Specification 3.1. 7 Part Strength CEA Insertion Limi for Specifi ion 3.1. 8. Linear Heat Rate for Specifi on 3.2.1. Azimuthal Power Tilt -Tq Specification 3.2,3. DNBR for Specifica on 3.2.4, Axial Shape Index for Specification 3.2.5, Boron Concentration (Mode 6) for Specification 3.9.1. analytical methods used to determine the core operatlng limits shall those previously reviewed and approved by the NRC, speclfica1ly those described in the following documents:

---

COLR will contain the complete identification for each the Technical Specification referenced topical reports used to prepare the COLR (i .e .. report number. title, revision.

date, and any supplements). (continued)

PALO VERDE UN 5.6-3 AMENDMENT NO. .

Reporting Requirements 5.6 Reporting Requirements (continued) 5.6.5 Core Operating Limits Report (COLR) (continued) "CE Method for Control Element Assembly ection Analysis," CENPD-0190-A, (Methodology for Specification 3.1.7, Regulating CEA Insertion Limits). "The ROCS and DIT Computer Codes for Nuclear Design," CENPD 266-P ,[Methodology for Specifications 3.1 1, Shutdown Margin -Reactor Trip Breakers Open: 3.1.2, Shutdown Margin -Reactor Trip Breakers Closed, 3.1.4, Moderator Temperature Coefficient BOL and EOL 3.1.7, Regulating CEA Insertion Limi and 3.9.1, (Mode "Safety Eva'luation Report related to the nal Design of the Standard Nuclear Steam Supply Reference Systems CESSAR System 80, Docket No. STN 50-470, "NUREG-0852 (November 1981), Supplemen No.1 (March 1983), No.2 (September 1983), NO.3 (December 1987) [Methodology for Specifi ions 312. Shutdown Margin Reactor p Breakers Closed: 3.1.4, Moderator Temperature Coeffiei BOL and COL liml ; 3.3.12. Boron Dilution Alarm System: 31.5, CEA Alignment; 3.1.7. Regulating

[EA Insertion Limits; 3.1 8, Part Strength CEA Insertion Limi and 3.2.3, Azimuthal Power "Modified stical Combination of Uncertainties," CEN-356(V)-P-A and "System 80'" Inlet Flow Distribution," Supplement I-P to Enclosure 1 P to LD 82 054, (Methodology for Specifi ion 32,4, DNBR and 3.2.5 Axial Shape Index). "lculative Methods for the CE Large Break LOCA Evaluation Model." CENPD-132, (Methodology for Specification 3.2 1. Linear Heat Rate). "Calculative Methods for the CE Small Break LOCA Evaluation Model," CENPD 137-P, (Methodology for Specification 3.2.1. Linear Heat Rate). (cont-i nued) PALO VERDE UNI 5.6-4 AMENDMENT NO. ,

5.6 Reporting Requirements 5.6 Reporting Requirements 5.6.5 Core Operating Limits Report (COLR) (continued)

7. Letter: 0.0, Parr (NRC) to F. M. Stern (CE). dated June 13. 1975 (NRC Staff Review of the Combustion Engineering ECCS Evaluation Model) NRC approval for: 5,6.5.b.6.

8. Letter: K, Kniel (NRC) to A, E. Scherer (CE). dated September

27. 1977 (Evaluation of Topical Reports CENPD 133. Supplement 3-P and CENPD-137, Supplement 1-P). NRC approval for 5.6.5.b,6.

9. "Fuel Rod Maximum Allowable Pressure," CEN-372 P-A, (Methodology for Specification 3,2.1. Linear Heat Rate). 10. Letter: A. C, Thadani (NRC) to A. E. Scherer (CE).dated Apri 1 10, 1990. ("Acceptance for Reference CE TORi ca 1 Report CEN-372 P"). NRC approval for 5.6.5.b.9.

11. "Arizona Public Service Company PWR Reactor Physics Methodology Using CASMO-4/SIMULATE-3." [Methodology for Specifications 31.1. Shutdown Margin Reactor Trip Breakers Open: 3,1.2, Shutdown Margin -Reactor Trip Breakers Closed: 3,1.4. Moderator Temperature Coefficient; 3.1.7. Regulating CEA Insertion Limi and 3.9,1. Boron Concentration (Mode 6)J. 12. "Technical Manual for the CENTS Code," CE-NPD 282-P-A. Volumes 1 3. [Methodology for Specifications 3.1.2. Shutdown Margin Reactor Trip Breakers Closed: 3.1,4.Moderator Temperature Coefficient:

3.1.5. CEA Alignment:

3,1,7. Regulating CEA Insertion Llmits: 3.1.8. Part Strength (EA Insertion Limi and 3,23. Azimuthal Power It TqJ, 13, CENPD P-A "Implementation of ZIRLO ffi Cladding Materia in Nuclear Power Fuel Assembly Designs. 14. CENPD-188-A. "HERMITE.

A Multi-Dimensional Space Time Kinetics Code for PWR Transients." [Methodology for Specifications 3,1.2. Shutdown Margin Reactor Trip Breakers Closed: 3,1,4. Moderator Temperature Coefficient:

3.2,1. Linear Heat Rate: 3,2.3. Azimuthal Power Tllt: 3.2.4. DNBR: and 3.2.5. Axial Shape Index.J 15, CENPD-161-P-A. "TORC Code. A ComQuter Code for Determining the Thermal Margin of a Reactor Core,*[Methodology for Specifications 3.1,1. Shutdown Reactor Trip Breakers Open; 3.1.2. Shutdown Reactor ip Breakers Closed: 31,4. Moderator Temperature Coefficient:

3.21, Linear Heat (continued)

PALO VERDE UNITS 1.2.3 5.6 5 AMENDMENT NO, .

Reporting Requirements 5.6 5.6 Reporting Requirements Core Operating Limits Report (COLR) (continued)

Rate: 3.2.3, Azimuthal Power It; 3.2.4, DNBR: and 3.2.5, Axial Shape Index.J 16. CEN-160(S)-P. "CETOP-D Code Structures and Modeling Methods for San Nuclear Generating Station Units 2 and 3." NRC in "Safety Evaluation related to Palo Verde Nuclear Generating Station. Unit 2 (PVNGS-2)Issuance of on Replacement of Steam Generators and Uprated Power Operation. (September 29, 2003)."[Methodology for Specifications 3.1.1. Shutdown Margin Reactor Trlp Open: 3.1.2. Shutdown Reactor Trip Closed: 3.1.4, Moderator Temperature Coefficient; 3.2.1, Linear Heat Rate: 3.2.3. Azimuthal Power Tilt: 3.2.4. DNBR: and 3.2.5. Axial Shape Index.J 17. "Safety Evaluation ated to Palo Verde Nuclear Generating Station. Unit 2 (PVNGS 2) Issuance of Amendment on Replacement of Steam Generators and Uprated Power Operation. (September

29. 2003) and "Safety Evaluation related Palo Verde Nuclear Generating Station. Units 1, 2. and 3 Issuance of Amendments Re: Replacement of Steam Generators and Uprated Power Operations and Associated Administrative Changes, (November

16. [Methodology for Specifications 3.1.1. Shutdown Margin-Reactor Trip Breakers Open; 3.1.2. Shutdown Margin-Reactor Trip Breakers Closed: 3.1.4, Moderator Coefficient; 3.1.5. CEA Alignment:

3.1.7, Regulating Insertion Limits: 3.1.8, Part Length or Part Strength CEA Insertion Limits: 3.2.1. Linear Heat Rate; 3.2.3. Azimuthal Power Tilt; 3.2.4, DNBR; and 3.2.5. Shape Index: 3.3.12, Boron Dilution Alarm (BOAS): and 3.9.1. Boron Concentration (Mode 6).J 18. CEN-310 P-A. Methodology Changes for the CPC Improvement

[Methodology for Specifications 3.2.1, Linear Heat Rate; 3.2.3, Azimuthal Power Tilt: 3.2.4. DNBR: and 3.2.5. Axial Shape Index.J 19. CENPD-183-A. "Loss of Flow, C E Methods for Loss of Flow Analysis." [Methodology for Specifications 3.2.1. Linear Heat Rate: 3.2.3, Azimuthal Power Tilt; 3.2.4. DNBR; and 3.2.5. Axial Shape Index.J (continued)

PALO VERDE UNITS 5.6-6 AMENDMENT NO. 174 5.6 Reporting Requirements 5.6 Reporting Requirements 5.6.5 Core Operating Limits Report (COLR) (continued)

20. CENPD-382-P .

for Core Designs Containing Erbium Burnable Absorbers.'

[Methodology for Specifications 3.1.1. Shutdown Margin Reactor Trip Breakers Open; 3.1.2. Shutdown Margin Reactor Trip Breakers Closed: and 3 1.4, Moderator Temperature Coefficient.]

21. CEN 386-P-A, "Verification of the Acceptability of a 1 Pin Burnup Limit of 60 MWD/kgU for Combustion Engineering 16 x 16 PWR Fuel" [Methodology for Specifi cati ons 3.1.1, Shutdown Margin Reactor Trip Breakers Open;3.1.2.Shutdown Margin-Reactor Trip Breakers Closed: and 3.1.4. Moderator Temperature Coeffi ent.J c. The core operating limi shall be determined such that all applicable limits (e.g .. fuel thermal mechanical limits. core thermal hydraulic limi . 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 mid cycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC. (continued)

PALO VERDE LIN 1. 2,3 5.6-7 NO. +/-B,'? 174 Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.6 PAM Report When a report is required by Condition B or F of LCO 3.3.10, "Post Accident Monitoring (PAM) Instrumentation, II a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability.

and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status. 5.6.7 Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report sha 11 include a descri pti on of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. 5.6.8 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed

'in accordance with the Specification 5.5.9, Steam Generator (SG)Program. The report shall include: The scope of inspections performed on each SG. Active degradation mechanisms found. Nondestructive examination techniques utilized for each degradation mechanism. Location, orientation (if linear), and measured sizes (if available) of service induced indications. Number of tubes plugged during the inspection outage for each active degradation mechanism. Total number and percentage of tubes plugged to date. The results of condition monitoring, including the results of tube pulls and in-situ testing. (continued)

PALO VERDE UNITS 1,2.3 5.6-8 NO. +/-+4. 178 Reporting Requirements 5.6 Reporting Requirements (continued) 5.6.9 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) RCS pressure and temperature limi for heatup. cool down , low temperature operation.

criticality.

and hydrostatic ng as well as heatup and cooldown rates shall be established and documented in the PTLR for the following Technical Specifications (TSs): TS 3.4.3, RCS Pressure and Temperature (PIT) Limits; TS 3.4.6. RCS Loops -Mode 4: 3. 3.4.7. RCS Loops -Mode 5 Loops lled: TS 3.4.11. Pressurizer Safety Valves -Mode 4; and TS 3.4. ,Low Temperature Overpressure Protecti on (LTOP) System. The analytical methods used to determine the RCS pressure and temperature limits shall be those previously reviewed and approved by the NRC, speci cally those described in the following document: CE NPSD 683-A, Revision 6, HDevelopment a RCS Pressure and Temperature Limits Report for the Removal of P Limits and LTOP Requirements from the Technical Specifications," April 2001. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto. PALO VERDE UNITS 5.6-9 AMENDMENT NO.

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area In addition to the provlslons of 10 CFR 20.1601. the following controls provide an alternate method for controlling access to high radiation areas as provided by paragraph 20.1601(c) of 10 CFR part 20. High radiation areas, as defined in 10 CFR 20. in which the intensity of radiation is > 100 mrem/hr but $ 1000 mrem/hr. shall be barricaded and conspicuously posted as a high radiation area and entrance thereto shall be controlled by requiring issuance of a Radiation Exposure Permit (REP).Individuals qualified in radiation protection procedures (e.g .. Radiation Protection Technicians) or personnel continuously escorted by such individuals may be exempt from the REP issuance requirement during the performance of their assigned duties in high radiation areas with exposure rates $ 1000 mrem/hr. provided they are otherwise following plant radiation protection procedures for entry into such high radiation areas. Any individual or group of individuals permitted to enter such areas shall be provided with or accompanied by one or more of the followi ng: A radiation monitoring device that continuously indicates the radiation dose rate in the area. A radiation monitoring device that continuously integrates the radiation dose rate in the area and alarms when a preset -integrated dose is received.

Entry into such areas with this monitoring device may be made after the dose rate levels in the area have been established and personnel are aware of them. An individual qualified in radiation protection procedures with a radiation dose rate monitoring device. who is responsible for providing positive control over the activities within the area and shall perform periodic radiation surveillance at the frequency specified by the Radiation Protection Section Leader or designated alternate in the REP.

PALO VERDE UN 5.7-1 AMENDMENT NO. +/-+/-l High Radiation Area 5.7 5.7 High Radiation Area In addition to the requirements of Specification 5.7.1. areas accessible to personnel with radiation levels such that an individual could receive in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> a dose greater than 1000 mrem shall be provided with locked or continuously guarded doors to prevent unauthorized entry and the keys shall be maintained under the administrative control of the Shift Manager on duty or Radiation Protection supervision.

Doors shall remain locked except during periods of access by personnel under an approved REP that shall specify the dose rate 1 eve 1 sin the i mmedi ate work areas and the maximum allowable stay mes for individuals in those areas. In lieu of the stay time specification of the REP. direct or remote (such as closed circuit TV cameras) continuous surveillance may be made by personnel quali ed in radiation protection procedures to provide positive exposure control over the activities being performed within the area. For individual high radiation areas accessible to personnel with radiation levels such that an individual could receive in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> a dose in excess of 1000 mrem (measurement made at 30 cm from source of radioactivity), that are located within large areas such as reactor containment.

where no enclosure exists for purposes of locking. and where no enclosure can be reasonably constructed around the individual area. that individual area shall be barricaded and conspicuously posted. and a flashing light shall be activated as a warning device. PALO VERDE UNITS 5.7-2 AMENDMENT NO. W APPENDIX B T0 FACILITY OPERATNG LICENSES NO. NPF-41, NPF-51 AND NPF-74 PALO VERDE NUCLEAR GENERATING STATION, UNITS 1, 2, AND 3 ARIZONA PUBLIC SERVICE COMPANY, ET AL DOCKET NOS. STN 50-528, STN 50-529 AND STN 50-530 ENVIRONMENTAL PROTECTION PLAN (NON-RADIOLOGICAL)

NOVEMBER 1987 8 7 12210t45 671125 PDR ADOC, bo5o0530 P PDR PALO VERDE NUCLEAR GENERATING STATION, UNITS, 1, 2 AND 3ENVIRONMENTAL PROTECTION PLAN (NON-RADIOLOGICAL)

TABLE OF CONTENTS Section Page 1.0 2.0 2.1 2.2 2.3 3.0 3.1 3.2 4.0 4.1 4.2 5.0 5.1 5.2 5.3 5.4 Objectives of the Environmental Protection Plan .Environmental Protection Issues .........Aquatic Issues. .................Terrestrial Issues. ............

...Cultural Resources Issues ............Consistency Requirements. ............Plant Design and Operation. ...........Changes Required for Compliance with Other Enviro Environmental Conditions.

............Unusual or Important Environmental Events ....Environmental Monitoring. ..........

Administrative Procedures ..........

Review and Audit. ................Records Retention

................Changes in Environmental Protection Plan. ....Plant Reporting Requirements. .............* * * ....nmental Regulations............* * * * .......* ..*

• 9 3 4 4 4 4 S 5 6 7 7 7 9 9 9 9 9 1.0 Objectives of the Environmental Protection Plan The Environmental Protection Plan (EPP) is to provide for protection of environmental values during construction and operation of the nuclearfacility. The principal objectives of the EPP are as follows: (1) Verify that the station is operated in an environmentally acceptable manner, as established by the FES and other NRC environmental impact assessments.

• (2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.

(3) Keep NRC informed of the environmental effects of facility construction and operation and of actions taken to control those effects. 2.0 Environmental Protection Issues In the FES-OL dated February 1982, the staff considered the environmental impacts associated with the operation of the Palo Verde Nuclear Generating Station. Certain environmental issues were identified which required study or license conditions to resolve environmental concerns and to assure adequate protection of the environment.

2.1 Aquatic Issues Because there will be no station effluents discharged to natural surface water bodies, station operation will have no direct adverse impacts on the qualityof surface water. Therefore, there are no aquatic issues raised by the staff in the FES-OL.2.2 Terrestrial Issues No new terrestrial issues requiring environmental monitoring programs were identified in the FES-OL. The FES-CP did identify a program for monitoring the effects of salt deposition due to cooling tower drift. The requirements for this program specified in Subsection 4.2.2 of this EPP.2.3 Cultural Resources Issues Upon resolution of the final alignment of the PVNGS-to-Saouaro transmission line, the applicant will conduct an appropriate cultural resource survey relative to the corridor for NRC review and evaluation pursuant to condition 7.f. of the construction permit (FES-CP, p. iii). There is a need to protect any cultural resources sites identified in the survey which may be eligiblefor or which are included in the National Register of Historic Places. NRC requirements with regard to the cultural resources issues are specified in Subsection 4.2.1 of this EPP._ _ 3.0 Consistency Requirements 3.1 Plant Design and Operation The licensees may make chances in station design or operation or perform tests or experiments affecting the environment provided such changes, tests or experiments do not involve an unreviewed environmental question, and do not involve a change in the Environmental Protection Plan. Changes in plant design or operation or performance of tests or experiments which do not affect the environment are not subject to the requirements of this EPP. Activities governed by Subsection 3.2 of this EPP are not subject to the requirements-of this subsection.

Before enaaginq in additional construction or operational activities which may affect the environment, the licensees shall prepare and record an environmental evaluation of such activity*.

When the evaluation indicates that such activity-involves an unreviewed environmental question, the licensees shall provide a written evaluation of such activities and obtain prior approval from the NRC.When such activity involves a chance in the Environmental Protection Plan, such activity and change to the Environmental Protection Plan may be implemented only in accordance with an appropriate license amendment as set forth in Subsection 5.3 of this EPP.A proposed change, test or experiment shall be deemed to involve an unreviewed environmental question if it concerns (1) a matter which may result in a significant increase in any adverse environmental impact previously evaluated in the Final Environmental Statement (FES) as modified by staff's testimony to the Atomic Safety and Licensing Board, supplements to the FES, environmental impact appraisals, or in any decisions of the Atomic Safety and Licensing Board; or (2) a significant change in effluents or power level or (3) a matter not previously reviewed and evaluated in the documents specified in (1) of this subsection, which may have a significant adverse environmental impact.The licensees shall maintain records of changes in facility design or operation and of tests and experiments carried out pursuant to this subsection.

These records shall include a written evaluation which provide bases for the deter-mination that the change, test, or experiment does not involve an unreviewed environmental question nor constitute a decrease in the effectiveness of this EPP to meet the objectives specified in Section 1.0. The licensees shall include as part of their Annual Environmental Operating Report (per Subsec-tion 5.4.1 of this EPP) brief descriptions, analyses, interpretations, andevaluations of such changes, tests and experiments.

• Activities are excluded from this requirement if all measurable nonradiological effects are confined to the on-site areas previously disturbed during site preparation and plant construction.

3.2 Changes Required for Compliance with Other Environmental Regulations Changes in plant design or operation and performance of tests or experiments whicfi are required to achieve compliance with other Federal, State, or localenvironmental regulations are not subject to the requirements of Subsection 3.1 of this EPP.

---6 -4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates, or could result in, significant environmental impact causally related to plant operation shall be recorded and promptly reported to the NRC within 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> by telephone,telegraph, or facsimile transmissions followed by a written report per Sub-section 5.4.2 of this EPP. The following are examples:

excessive bird impac-tion events, onsite plant or animal disease outbreaks, mortality or unusual occurrence of any species protected by the Endangered Species Act of 1973, fish kills, and an increase in nuisance organisms or conditions.

No routine monitoring programs are required to implement this condition.

4.2 Environmental Monitoring 4.2.1 Cultural Resources Section 4.3.6 of the FES-OL states, "No Archeological surveys have been undertaken in the PYNGS-to-Saouaro corridor because the construction of this line is not scheduled until 1984-1986.

When a final alignment for theSaguaro transmission line is selected, appropriate archeological surveys will X~ be undertaken and submitted for staff review and evaluation pursuant to condition 7.f. of the construction permit (FES-CP, p. iii)." The licensees should consult with the State Historic Preservation Office (SHPO) and the NRC in developing an appropriate cultural resource survey. A survey report will be submitted to NRC for review. Should the survey identify significant sites which may be eligible for the National Register of Historic Places, the licensees shall be required to provide the NRC with the information necessary to initiate a determination of eligibility request to the Keeper of the National Register.

The U.S. Department of Interior form entitled, "National Register of Historic Places Inventory-Nomination Form," should be filled out in detail with appropriate maps and other materials for each such site and returned to the NRC. Item 12 of the form need not be filled out. Thelicensees should refer to the Federal Register, September 21, 1977, Part 11, for detailed guidance. The NRC requests the licensees to take appropriate measures to protect such sites during the determination of eligibility process.Upon receipt and review of the information, the NRC will forward the materials to the Keeper for action. If the Keeper rules the sites are not eligible, the finding will be filed and this subsection of the EPP is fully satisfied with nofurther action required.If the Keeper rules that any of the sites are eligible for the National Register, the licensees are required to provide the NRC with the information with regard to completing a determination of effect which the operation and maintenance activities of the plant may have on the eligible sites. The licensees should follow the steps presented in 36 CFR 800.3 and 36 CFR 800.4 in developing the information. Upon receipt of the information, the NRC, in consultation withthe SHPO, will complete the determination of effect process. If the determi-nation results in a no effect determination as provided in 36 CFR 800.4(4)(B)(1), the documentation will be filed and this subsection of the EPP is fully satisfied with no further action required.

--7 -If the determination results in an effect determination, the licensees will be required to provide the NRC with information adequate to document the effect determination and an appropriate action program which the licensees have devel-oped in consultation with the SHPO and concurred in by the SHPO. Upon review of the program, the NRC will forward the documentation to the Advisory Council onHistoric Preservation (ACHP) for comment.After ACHP comment is received by NRC, the program will be revised, if necessary, to incorporate any comments provided by the ACHP. The licensees shall then proceed, in consultation with the SHPO, to implement the proposed program.Upon completion of the program, a report shall be submitted to the NRC which will include a description of the results of the program and the disposition of data recovered (if applicable).

Upon submittal of this report, this subsection of the EPP is fully satisfied with no further action required.4.2.2 Terrestrial Ecology MonitoringThe licensees will implement the Salt Deposition and Impact Monitoring Plan provided to NRC by letter dated May 17, 1985 from E. E. Van Brunt, Jr., Arizona Nuclear Power Project, to G. W. Knighton, U. S. Nuclear RegulatoryCommission. The purpose of the Plan is to assess the impacts of cooling towersalt drift on soils, native vegetation and agricultural crops in the PVNGS vicinity.The monitoring program shall commence by the onset of commercial operation of the first unit and continue for a minimum of three full years after the onset of operation of all three PVNGS Units or until such time that the licensees can demonstrate to the satisfication of the NRC that the objectives of the study have been fulfilled.

Annual monitoring reports shall be submitted tothe NRC for review.The licensees may not make changes in the procedures described in the documentwithout prior NRC approval unless the proposed changes do not affect the program objectives described in the introduction to the Monitoring Plan. For example, changes in the procedures, which affect sampling frequency, location,gear, or replication, can be made without prior NRC approval, but shall be reported to the NRC within 30 days after their implementation.

These reports shall describe the changes made, the reasons for making the changes, and a statement showing how continuity of the study will be affected.

Any modifications or chances of the initially approved program shall be governed by the need to maintain consistency with previously used procedures so that direct comparisons of data are technically valid. Such modifications or changes shall be justified and supported by adequate comparative sampling programs or studies demonstrating the comparability of results or which provide a basis for making adjustments that would permit direct comparisons.

The licensees shall maintain at the site, available for inspection, a copy of the Monitoring Plan with all revisions. 5.0 Administrative Procedures 5.1 Review and AuditThe licensees shall provide for review and audit of compliance with the Environmental Protection Plan. The audits shall be conducted independently of the individuals or groups responsible for performing the specific activity.

A description of the organizational structure utilized to achieve the independent review and audit function and the results of the audit activities shall be main-tained and made available for inspection.

5.2 Records Retention Records and logs relative to the environmental aspects of plant operation shall be made and retained in a manner convenient for review and inspection.

These records and logs shall be made available to NRC on request.Records of modifications to plant structures, systems and components determined to potentially affect the continued protection of the environment shall be retained for the life of the plant.

All other records, data and loos relating to this EPP shall be retained for five years or, where applicable, in accordance with the requirements of other agencies.5.3 Changes in Environmental Protection Plan Request for change in the Environmental Protection Plan shall include an assessment of the environmental impact of the proposed change and a supportingjustification. Implementation of such changes .in the EPP shall not commence prior to NRC approval of the proposed chances in the form of a license amendment incorporating the appropriate revision to the Environmental Protection Plan.5.4 Plant Reporting Requirements 5.4.1 Routine Reports An Annual Environmental Operating Report describing implementation of this EPP for the previous year shall be submitted to the NRC prior to May 1 of each year. The initial report shall be submitted prior to May I of the year following issuance of the operating license. The period of the first report shallbegin with the date of issuance of the operating license for the first opera-tional unit.The report shall include summaries and analyses of the results of the environ-mental protection activities required by Subsection 4.2 of this Environmental Protection Plan for the report period, including a comparison with preopera-tional studies, operational controls, and an assessment of the observed impactsof the plant operation on the environment (as appropriate).

If harmful effects or evidence of trends towards irreversible damage to the environment are observed, the licensees shall provide a detailed analysis of the data and a proposed course of action to alleviate the problem. The Annual Environmental Operating Report shall also include:(a) A list of EPP noncompliances and the corrective actions taken to remedy them.(b) A list of all changes in station design or operation, tests, and experi-ments made in accordance with Subsection 3.1 of this EPP which involved a potentially significant unreviewed environmental issue.(c) A list of nonroutine reports submitted in accordance with Subsection 5.4.2 of this EPP.In the event that some results are not available by the report due date, the report shall be submitted noting and explaining the missing results. The missing data shall be submitted as soon as possible in a supplementary report.5.4.2 Nonroutine Reports A written report shall be submitted to the NRC within 30 days of occurrence of nonroutine event. The report shall (a) describe, analyze, and evaluate the event, including the extent and magnitude of the impact and plant operating characteristics, (b) describe the probable cause of the event, (c) indicate thi action taken to correct the reported event, (d) indicate the corrective action taken to preclude repetition of the event and to prevent similar occurrencesinvolving similar components or systems, and (e) indicate the agencies notifiel and their preliminary responses.

e d Events reportable under this subsection which also Federal, State or local agencies shall be reported reporting requirements in lieu of the requirements NRC shall be provided a copy of such report at the to the other agency.require reports to other in accordance with those of this subsection.

Thesame time it is submitted MAY APPENDIX C ANTITRUST CONDITIONS LICENsE No. NPF-41 Arizona Public'Service Company and the Salt River Project Agricultural Improvement and Power District shall comply with the following antitrust conditions: In connection with the antitrust conditions, the following definitions are used herein: -Bulk Power" means the electric power, and any attendant energy, supplied or made available at transmission or subtransmission voltage by one entity to another. "Entity" means a. person, private or public corporation, a municipality, a cooperative, an association, a joint stock association or business trust owning, operating or proposfng in good faith to own or operate equipment or facilities for the generation, transmission or distribution of electricfty to or for the publfc as a utility. "Joint Applicant(s)" means the Arizona Public Service Company and c. the Salt River Project Agricultural Improvement and Power District. A. Each joint applicant will transmit Bulk Power over fts transmission system, between or among two or more Entities with which it is interconnected, or wf" be interconnected in the future. without restrictions on use or resale of the power so transmitted, provided such services can reasonably be accommodated from a technical standpoint without impairing each joint applicant's reliability or its own use of its facilities. Each joint applicant is obligated under this condition to transmit Power on the terms stated above, and in connection with each joint applicant's plan to construct new transmission facilities for its own use. to include in fts planning and construction program sufficient transmissfon capacity for such Bulk Power transactfons, provided that such applfcant has received sufficfent advance notice as may be necessary from a technical standpoint to accommodate the requirements of requesting entity. and further provided that such entity(ies}

are obligated as may be agreed (i) to share the cipital, operating and mlintenance costs of such new transmission facilities to the extent that additional costs burdens would be imposed on such joint applicant or (ii) to compensate the joint applicant fully for the use of its system. e*

• 3. The foregoing shall be implemented in a manner consistent with the provisions of the Federal Power Act as applicable and all rates. charges or practices in connection herewith are to be subject to the approval of regulatory agencies having jurisdiction over them *. *

• ADDITIONAL FACILITY OPERATING LICENSE NOS. NPF-41, NPF-51, AND The licensee shall comply with the following conditions on the schedules noted below: Amendment Number Additional Conditions Implementation Date Upon implementation ofTS Amendment No. 171 adopting TSTF-448, Revision 3, the determination of control room envelope (CRE) unfiltered air inleakage as required by SR 3.7.11.4, in accordance with TS 5.5. 17.c.(i), the assessment of CRE habitability as required by Specification 5.5.17.c.(ii), and the measurement of CRE pressure as required by Specification 5.5. 17.d. shall be considered met. Following implementation of TS Amendment No. 171 adopting TSTF-448.

Revision 3: (a) The first performance of SR 3.7.11.4.

in accordance with Specification 5.5.17.c.{i}, shall be as follows for each unit: Unit 1: Within the specified Frequency of 6 years plus the 18-month allowance of SR 3.0.2, as measured from August 9,2005, the date of the most recent successful tracer gas test on Unit 1. Unit Within the first 18 months of implementation, because the time period Since the most recent successful tracer gas test on Unit 2 (April 26, 2001) is greater than 6 years. Unit Within the specified Frequency of 6 years plus the 18-month allowance of SR 3.0.2, as measured from August 15. 2005, the date of the most recent successful tracer gas test on Unit 3. The amendment shall be implemented within 180 days from the date of its issuance Amendment No. 171 Amendment Number 171 (Cont'd) Additional Conditions (b) The first performance of the periodic assessment of CRE habitability, Specification 5.5.17.c.(ii), shall be as follows for each unit: Unit 1: Within 3 years plus the 9-month allowance of SR 3.0.2, as measured from August 9, 2005, the date of the most recent successful tracer gas test on Unit 1, or within the first 9 months of implementation, whichever is later. Unit 2: Within the first 9 months of implementation, because the time period since the date of the most recent successful tracer gas test on Unit 2 (April 26, 2001) is greater than 3 years. Unit 3: Within 3 years plus the 9-month allowance of SR 3.0.2, as measured from August 15, 2005, the date of the most recent successful tracer gas test on Unit 3, or within the first 9 months of implementation, whichever is later. (c) The first performance of the periodic measurement of CRE pressure.

Specification 5.5.17.d, shall be as follows for each unit: Unit 1: Within 18 months plus the 138 days allowed by SR 3.0.2, as measured from May 16, 2007, the date of the most recent successful pressure measurement test on Unit 1, or within the first 138 days of implementation, whichever is later. Unit Within 18 months plus the 138 days allowed by SR 3.0.2, as measured from September 18, 2006, the date of the most recent successful pressure measurement test on Unit 2. or within the first 138 days of implementation, whichever is later. Unit Within 18 months plus the 138 days allowed by SR 3.0.2, as measured from November 23, 2007, the date of the most recent successful pressure measurement test on Unit 3. or within the 'first 138 days of implementation, whichever is later. Implementation Date Amendment No. 171