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50-370, 50-369, Improved Technical Specifications, Mcguire Nuclear Station, Units No. 1 and 2 (Volume 1)
	ML033070046
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Site:	McGuire, Mcguire
Issue date:	12/05/2003
From:	; Duke Energy Corp
To:	Anand R; NRC/NRR/DRIP/RLEP
	Anand R NRR/DRIP/RLEP, 415-1146
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50-370 50-369 IMPROVED TIECIINICAL SPi!CIFiCATioNS McGuire Nuclear Station, Units No. 1 and 2 (Volume I)

TABLE OF CONTENTS 1.0 USE AND APPLICATION ................................................. 1.1-1 1.1 Definitions ................................................. 1.1-1 1.2 Logical Connectors ................................................. 1.2-1 1.3 Completion Times ................................................. 1.3-1 1.4 Frequency ................................................. 1.4-1 2.0 SAFETY LIMITS (SLs) ................................................. 2.0-1 2.1 SLs ................................................. 2.0-1 2.2 SL Violations ................................................. 2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ............... 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY .............................. 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ................................................. 3.1.1-1 3.1.1 SHUTDOWN MARGIN (SDM) ................................................. 3.1.1-1 3.1.2 Core Reactivity ................................................. 3.1.2-1 3.1.3 Moderator Temperature Coefficient (MTC) ..................................... 3.1.3-1 3.1.4 Rod Group Alignment Limits ................................................. 3.1.4-1 3.1.5 Shutdown Bank Insertion Limits................................................. 3.1.5-1 3.1.6 Control Bank Insertion Limits ................................................. 3.1.6-1 3.1.7 Rod Position Indication ................................................. 3.1.7-1 3.1.8 PHYSICS TESTS Exceptions ................................................. 3.1.8-1 3.2 POWER DISTRIBUTION LIMITS ................................................. 3.2.1-1 3.2.1 Heat Flux Hot Channel Factor (Fa(X,Y,Z)) ...................................... 3.2.1-1 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FeH(X,Y)) ................... 3.2.2-1 3.2.3 AXIAL FLUX DIFFERENCE (AFD) ................................................. 3.2.3-1 3.2.4 QUADRANT POWER TILT RATIO (QPTR) .................................... 3.2.4-1 3.3 INSTRUMENTATION ................................................. 3.3.1-1 3.3.1 Reactor Trip System (RTS) Instrumentation ................................... 3.3.1-1 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation ................................... 3.3.2-1 3.3.3 Post Accident Monitoring (PAM) Instrumentation ............................ 3.3.3-1 3.3.4 Remote Shutdown System ................................... 3.3.4-1 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation ... 3.3.5-1 3.3.6 Containment Purge and Exhaust Isolation Instrumentation ............................ 3.3.6-1 3.4 REACTOR COOLANT SYSTEM (RCS) ............................ 3.4.1-1 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits ................................ 3.4.1-1 3.4.2 RCS Minimum Temperature for Criticality................................ 3.4.2-1 3.4.3 RCS Pressure and Temperature (PIT) Limits ................................ 3.4.3-1 3.4.4 RCS Loops-MODES 1 and 2 ................................ 3.4.4-1 3.4.5 RCS Loops-MODE 3 ................................ 3.4.5-1 McGuire Units 1 and 2 i Amendment Nos. 1841166

TABLE OF CONTENTS (continued) 3.4 REACTOR COOLANT SYSTEM (RCS) (continued) 3.4.6 RCS Loops-MODE 4 ................................................ 3.4.6-1 3.4.7 RCS Loops-MODE 5, Loops Filled ............................................... 3.4.7-1 3.4.8 RCS Loops-MODE 5, Loops Not Filled ......................................... 3.4.8-1 3.4.9 Pressurizer ............................................... 3.4.9-1 3.4.10 Pressurizer Safety Valves ................................................ 3.4.10-1 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) ...................... 3.4.11-1 3.4.12 Low Temperature Overpressure Protection (LTOP) System ........... 3.4.12-1 3.4.13 RCS Operational LEAKAGE ................................................ 3.4.13-1 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage ................................. 3.4.14-1 3.4.15 RCS Leakage Detection Instrumentation ........................................ 3.4.15-1 3.4.16 RCS Specific Activity ............................................... 3.4.16-1 3.4.17 RCS Loop-Test Exceptions ................................................ 3.4.17-1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) ............................. 3.5.1-1 3.5.1 Accumulators ............................................... 3.5.1-1 3.5.2 ECCS-Operating ............................................... 3.5.2-1 3.5.3 ECCS-Shutdown ............................................... 3.5.3-1 3.5.4 Refueling Water Storage Tank (RWST) .......................................... 3.5.4-1 3.5.5 Seal Injection Flow............................................... 3.5.5-1 3.6 CONTAINMENT SYSTEMS ................................................ 3.6.1-1 3.6.1 Containment ............................................... 3.6.1-1 3.6.2 Containment Air Locks ................................................ 3.6.2-1 3.6.3 Containment Isolation Valves ................................................ 3.6.3-1 3.6.4 Containment Pressure ................................................ 3.6.4-1 3.6.5 Containment Air Temperature ............................................... 3.6.5-1 3.6.6 Containment Spray System ............................................... 3.6.6-1 3.6.7 Hydrogen Recombiners ............................................... 3.6.7-1 3.6.8 Hydrogen Skimmer System (HSS) ................................................ 3.6.8-1 3.6.9 Hydrogen Mitigation System (HMS) ............................................... 3.6.9-1 3.6.10 Annulus Ventilation System (AVS) ................................................ 3.6.10-1 3.6.11 Air Retum System (ARS) ............................................... 3.6.11-1 3.6.12 Ice Bed ............................................... 3.6.12-1 3.6.13 Ice Condenser Doors ................................................ 3.6.13-1 3.6.14 Divider Barrier Integrity ................................................ 3.6.14-1 3.6.15 Containment Recirculation Drains ................................................ 3.6.15-1 3.6.16 Reactor Building ............................................... 3.6.16-1 3.7 PLANT SYSTEMS ............................................... 3.7.1-1 3.7.1 Main Steam Safety Valves (MSSVs) ............................................... 3.7.1-1 3.7.2 Main Steam Isolation Valves (MSIVs) ............................................. 3.7.2-1 3.7.3 Main Feedwater Isolation Valves (MFIVs),

Main Feedwater Control Valves (MFCVs), MFCV's Bypass Valves and Main Feedwater (MFW) to Auxiliary Feedwater (AFW) Nozzle Bypass Valves (MFW/AFW NBVs) ... 3.7.3-1 3.7.4 Steam Generator Power Operated Relief Valves (SG PORVs) ... 3.7.4-1 McGuire Units 1 and 2 ii Amendment Nos. 1841166

TABLE OF CONTENTS (continued) 3.7 PLANT SYSTEMS (continued) 3.7.5 Auxiliary Feedwater (AFW) System ............................................... 3.7.5-1 3.7.6 Component Cooling Water (CCW) System ..................................... 3.7.6-1 3.7.7 Nuclear Service Water System (NSWS) ......................................... 3.7.7-1 3.7.8 Standby Nuclear Service Water Pond (SNSWP) ............................ 3.7.8-1 3.7.9 Control Room Area Ventilation System (CRAVS) ........................... 3.7.9-1 3.7.10 Control Room Area Chilled Water System (CRACWS) ................... 3.7.10-1 3.7.11 Auxiliary Building Filtered Ventilation Exhaust System (ABFVES) .......................................... 3.7.11-1 3.7.12 Fuel Handling Ventilation Exhaust System (FHVES) ...................... 3.7.12-1 3.7.13 Spent Fuel Pool Water Level .......................................... 3.7.13-1 3.7.14 Spent Fuel Pool Boron Concentration ......................................... 3.7.14-1 3.7.15 Spent Fuel Assembly Storage ......................................... 3.7.15-1 3.7.16 Secondary Specific Activity .......................................... 3.7.16-1 3.8 ELECTRICAL POWER SYSTEMS ......................................... 3.8.1-1 3.8.1 AC Sources-Operating ......................................... 3.8.1-1 3.8.2 AC Sources-Shutdown ......................................... 3.8.2-1 3.8.3 Diesel Fuel Oil and Starting Air ......................................... 3.8.3-1 3.8.4 DC Sources-Operating ......................................... 3.8.4-1 3.8.5 DC Sources-Shutdown ......................................... 3.8.5-1 3.8.6 Battery Cell Parameters ......................................... 3.8.6-1 3.8.7 Inverters-Operating ......................................... 3.8.7-1 3.8.8 Inverters-Shutdown .......................................... 3.8.8-1 3.8.9 Distribution Systems-Operating .......................................... 3.8.9-1 3.8.10 Distribution Systems-Shutdown .......................................... 3.8.10-1 3.9 REFUELING OPERATIONS .......................................... 3.9.1-1 3.9.1 Boron Concentration ......................................... 3.9.1-1 3.9.2 Unborated Water Source Isolation Valves ...................................... 3.9.2-1 3.9.3 Nuclear Instrumentation ......................................... 3.9.3-1 3.9.4 Containment Penetrations ......................................... 3.9.4-1 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation-High Water Level ... 3.9.5-1 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation-Low Water Level ............................... 3.9.6-1 3.9.7 Refueling Cavity Water Level ............................... 3.9.7-1 4.0 DESIGN FEATURES ............................... 4.0-1 4.1 Site Location ............................... 4.0-1 4.2 Reactor Core ............................... 4.0-1 4.3 Fuel Storage...........................................................................................04.-1 McGuire Units and 2 iii Amendment Nos. 1841166

TABLE OF CONTENTS (continued) 5.0 ADMINISTRATIVE CONTROLS ....................... 5.1-1 5.1 Responsibility ....................... 5.1-1 5.2 Organization ...................... 5.2-1 5.3 Unit Staff Qualifications ....................... 5.3-1 5.4 Procedures ....................... 5.4-1 5.5 Programs and Manuals ...................... 5.5-1 5.6 Reporting Requirements ....................... 5.6-1 5.7 High Radiation Area ...................... 5.7-1 McGuire Units and 2 iv Amendment -Nos. 184-l166

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions J t ---- ~~~~-------______

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

ACTUATION LOGIC TEST An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices.

AXIAL FLUX DIFFERENCE AFD shall be the difference in normalized flux signals (AFD) between the top and bottom halves of a two section excore neutron detector.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel so that it responds within the required range and accuracy to known input. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, interlock, display, and trip functions. Calibration of instrument channels with resistance temperature detector (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.

The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping calibrations or total channel steps so that the entire channel is calibrated.

(continued)

McGuire Units 1 and 2 1 .1-1 Amendment Nos. 184/166

Definitions 1.1 1.1 Definitions (continued)

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

CHANNEL OPERATIONAL A COT shall be the injection of a simulated or actual signal TEST (COT) into the channel as close to the sensor as practicable to verify the OPERABILITY of required alarm, interlock, and trip functions. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that provides cycle REPORT (COLR) specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Unit operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 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 Table IlIl of TID-14844, AEC, 1962, Calculation of Distance Factors for Power and Test Reactor Sites.!

E -AVERAGE E shall be the average (weighted in proportion to the DISINTEGRATION ENERGY 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/d) for isotopes, other than iodines, with half lives > 10 minutes, making up at least 95% of the total noniodine activity in the coolant.

(continued)

McGuire Units 1 and 2 1.1 -2 Amendment Nos. 184/166

Definitions 1.1 1.1 Definitions (continued)

ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time interval from FEATURE (ESF) RESPONSE when the monitored parameter exceeds its ESF actuation TIME 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 time may be verified for selected components provided that the components and the methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified 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 to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator (SG) to the Secondary System;

b. Unidentified LEAKAGE All LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE;

c. Pressure Boundary LEAKAGE LEAKAGE (except SG LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

(continued)

McGuire Units and 2 1.1 -3 Amendment Nos.206/1 87

Definitions 1.1 a

1.1 Definitions (continued)

MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing each master relay and verifying the OPERABILITY of each relay.

The MASTER RELAY TEST shall include a continuity check of each associated slave relay.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

NOMINAL TRIP SETPOINT The NOMINAL TRIP SETPOINT shall be the design value of a setpoint. The trip setpoint implemented In plant hardware may be less or more conservative than the NOMINAL TRIP SETPOINT by a calibration tolerance. Unless otherwise specified, if plant conditions warrant, the trip setpoint implemented in plant hardware may be set outside the NOMINAL TRIP SETPOINT calibration tolerance band as long as the trip setpoint is conservative with respect to the NOMINAL TRIP SETPOINT.

OPERABLE-OPERABIUTY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABIULTY 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 PHYSICS TEhSTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related Instrumentation. These tests are:

a. Described in Chapter 14 of the UFSAR;

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

c. Otherwise approved by the Nuclear Regulatory Commission.

(continued)

McGuire Units 1 and 2 1 .1-4 ATendment Nos. 194/175

Definitions 1.1 1.1 Definitions (continued)

QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper excore RATIO (QPTR) detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of 3411 MWt.

REACTOR TRIP The RTS RESPONSE TIME shall be that time interval from SYSTEM (RTS) RESPONSE when the monitored parameter exceeds its RTS trip setpoint TIME at the channel sensor until loss of stationary gripper coil voltage. 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 the methodology for verification have been previously reviewed and approved by the NRC.

SHUTDOWN MARGIN (SDM) 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 rod cluster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and

b. In MODES 1 and 2, the fuel and moderator temperatures are changed to the nominal zero power design level.

SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay. The SLAVE RELAY TEST shall include, as a minimum, a continuity check of associated testable actuation devices.

McGuire Units 1 and 2 1.1-5 Amendmenj Nos. 206L187

Definitions 1.1 1.1 Definitions (continued)

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip actuating device OPERATIONAL TEST and verifying the OPERABILITY of required alarm, interlock, (TADOT) and trip functions. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

McGuire Units 1 and 2 1.1-6 Amendment Nos. 206/187

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

MODES AVERAGE REACTIVITY % RATED REACTOR COOLANT CONDITION THERMAL TEMPERATURE MODE TITLE (k) POWER(a) (F) 1 Power Operation > 0.99 >5 NA 2 Startup > 0.99 <5 NA 3 Hot Standby < 0.99 NA > 350 4 Hot Shutdown(b) < 0.99 NA 350 > T ag> 200 5 Cold Shutdown(b) < 0.99 NA < 200 6 Refueling(C) NA NA NA (a) Excluding decay heat.

(b) All reactor vessel head closure bolts fully tensioned.

(c) One or rnore reactor vessel head closure bolts less than fully tensioned.

McGukre Units 1 and 2 1.1-7 Amendment Nos. 194/175

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

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

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

The successive levels of logic are identified by additional digits of the Required Action number and by successive indentations of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

(continued)

McGuire Units 1 and 2 1.2-1 Amendment Nos. 184/166

In this example the logical connector AND is used to indicate that when in Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-1 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify ...

AND A.2 Restore...

In this example the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

(continued)

McGuire Units 1 and 2 1.2-2 Amendment Nos. 184/166

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

McGuire Units 1 and 2 1.2-3 Amendment Nos. 184/166

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

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

Once a Condition has been entered, subsequent 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 apply to each additional failure, with Completion Times based on initial entry into the Condition.

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

McGuire Units 1 and 2 1.3-1 Amendment Nos. 184/166

Completion Times 1.3 1.3 Completion Times DESCRIPTION Completion Time extension, two criteria must first be met. The (continued) subsequent inoperability:

a. Must exist concurrent with the first inoperability; and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

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

The above Completion Time extension does not apply to a Completion Time with a modified time zero.' This modified time zero" may be expressed as a repetitive time (i.e., once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ,' where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase from discovery. . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

(continued)

McGuire Units 1 and 2 1.3-2 Amendment Nos. 184/166

Completion Times 1.3 1.3 Completion Times (continued)

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

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to be in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months ) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months because the total time allowed for reaching MODE 5 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

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

(continued)

McGuire Units 1 and 2 1.3-3 Amendment Nos. 184/166

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

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

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

When a pump is declared inoperable, Condition A is entered. If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

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

LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, (continued)

McGuire Units 1 and 2 1.3-4 Amendment Nos. 184/166

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

LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

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

(continued)

McGuire Units 1 and 2 1.3-5 Amendment Nos. 184/166

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore Function X 7 days Function X train to OPERABLE train status. AND inoperable.

10 days from discovery of failure to meet the LCO B. One B.1 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y train to OPERABLE train status. AND inoperable.

10 days from discovery of failure to meet the LCO C. One C.1 Restore Function X 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function X train to OPERABLE train status.

inoperable.

OR AND One C.2 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y train to OPERABLE train

status.

inoperable.

(continued)

McGuire Units 1 and 2 1.3-6 Amendment Nos. 184/166

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 Time, Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected 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 Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal time zero for beginning the Completion Time "clock". In this instance, the Completion Time time zero is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.

(continued)

McGuire Units 1 and 2 1.3-7 Amendment Nos. 184/166

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or A.1 Restore valve(s) to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months more valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months met.

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

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

(continued)

McGuire Units 1 and 2 1.3-8 Amendment Nos. 184/166

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

ACTIONS SpreCntoetysa---------NOTE----- inopralevave Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months more valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months met.

The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

(continued)

McGuire Units 1 and 2 1.3-9 Amendment Nos. 184/166

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

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Perform SR 3.x.x.x. Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months channel inoperable. OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to

< 50% RTP.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated Completion Time not met.

(continued)

McGuire Units 1 and 2 1.3-1 0 Amendment Nos. 184/166

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)

Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a once per' Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2),

Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met, Condition B is entered.

If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.

(continued)

McGuire Units 1 and 2 1.3-1 1 Amendment Nos. 184/166

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

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

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

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter' interval begins upon performance of Required Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2),

Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time (continued)

McGuire Units 1 and 2 1.3-1 2 Amendment Nos. 184/166

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

Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

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

McGuire Units 1 and 2 1.3-1 3 Amendment Nos. 184/166

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR)

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

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

(continued)

McGuire Units 1 and 2 1.4-1 Amendment Nos. 184/166

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4.

(continued)

McGuire Units 1 and 2 1 .4-2 Amendment Nos. 184/166

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-2 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector AND' indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level

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

The use of wonce' indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by NAND").

This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2. Thereafter' indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the oncew performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

(continued)

McGuire Units 1 and 2 1.4-3 Amendment Nos. 184/166

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP.

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

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

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

< 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power > 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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.

McGuire Units 1 and 2 1.4-4 Amendment Nos. 184/166

SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the SLs specified in Figure 2.1.1-1 for four loop operation.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5, the RCS pressure shall be maintained < 2735 psig.

2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2.2 In MODE 3, 4, or 5, restore compliance within 5 minutes.

McGuire Units 1 and 2 2.0-1 Amendment Nos. 184/166

SLs 2.0 670 660 650 640 0

630 C)

CU CD) 620 0.

610 600 590 580 _

0.0 0.2 0.4 0.6 0.8 1.0 1.2 Fraction of Rated Thermal Power Figure 2.1.1 1 Reactor Core Safety Limits -

Four Loops in Operation McGuire Units 1 and 2 2.0-2 Amendmeht Ns. 191 (Unit 1) 172 (Unit 2)

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2 and 3.0.7.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

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

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 3 within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ;

b. MODE 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

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

Exceptions to this Specification are stated in the individual Specifications.

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

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4.

LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall not be made except when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS.

Exceptions to this Specification are stated in the individual Specifications.

(continued)

McGuire Units 1 and 2 3.0-1 Amendment Nos. 184/166

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the required testing to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, additional evaluations and limitations may be required in accordance with Specification 5.5.15, Safety Function Determination Program (SFDP)."

If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

LCO 3.0.7 Test Exception LCOs 3.1.8 and 3.4.17 allow specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Test Exception LCOs is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

(continued)

McGuire Units 1 and 2 3.0-2 Amendment Nos. 184/166

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.8 LCOs including the associated ACTIONS shall apply to each unit individually unless otherwise indicated as follows:

a. Whenever the LCO refers to systems or components which are shared by both units, the ACTIONS will apply to both units simultaneously;

b. Whenever the LCO applies to only one unit, this will be identified in the Applicability section of the Specification; and

c. Whenever certain portions of a Specification contain operating parameters, setpoints etc., which are different for each unit, this will be identified in parentheses or footnotes. (For example, ...flow rate of 54,000 cfm (Unit 1) or 43,000 cfm (Unit 2)...').

McGuire Units 1 and 2 3.0-3 Amendment Nos. 184/166

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in tne Applicability for individual LCOs, unless otherwise stated in the SR.

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

SR 3.0.2 The specified Frequencyfor each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per. ..

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , and the risk impact shall be managed.

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

When the Surveillance is performed within the delay period .andthe.

Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

(continued)

McGuire Units and 2 3.0-4 Amendment Nos. 205/186

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall not be made unless the LCO's Surveillances have been met within their specified Frequency. This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS.

SR 3.0.5 Surveillance Requirements shall apply to each unit individually unless otherwise indicated as stated in LCO 3.0.8 for individual Specifications or whenever certain portions of a Specification contain surveillance parameters different for each unit, which will be identified in parentheses or footnotes.

McGuire Units 1 and 2 3.0-5 Amendment Nos. 184/166

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

LCO 3.1.1 SDM shall be within the limit specified in the COLR.

APPLICABILITY: MODE 2 with k < 1.0, MODES 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore 15 minutes SDM to within limit.

SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is within the limit specified in the COLR. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months McGuire Units 1 and 2 3.1 .1-1 Amendment Nos. 184/166

Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within +/- 1% Ak/k of predicted values.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Measured core reactivity A.1 Re-evaluate core design 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months not within limit. and safety analysis, and determine that the reactor core is acceptable for continued operation.

AND A.2 Establish appropriate 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months operating restrictions and SRs.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.1 .2-1 Amendment Nos. 184/166

Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 ~------NOTE----- --a---

The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel bumup of 60 effective full power days (EFPD) after each fuel loading.

Verify measured core reactivity is within . 1% Ak/k of Once prior to predicted values. entering MODE 1 after each refueling AND 31 EFPD thereafter McGuire Units 1 and 2 3.1 .2-2 Amendment Nos. 184/166

MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be that specified in Figure 3.1.3-1.

APPLICABILITY: MODE 1 and MODE 2 with keff > 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. MTC not within upper A.1 Establish administrative 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit. withdrawal limits for control banks to maintain MTC within limit.

B. Required Action and B.1 Be in MODE 2 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion kff < 1.0.

Time of Condition A not met.

C. MTC not within lower C.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limit.

McGuire Units 1 and 2 3.1 .3-1 Amendment Nos. 184/166

MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE 1 after each refueling SR 3.1.3.2 ------------ NOTES----

1. Not required to be performed until 7 effective full power days (EFPD) after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm.

2. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.

3. SR 3.1.3.2 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of < 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COLR.

Verify MTC is within lower limit. Once each cycle McGuire Units 1 and 2 3.1 .3-2 Amendment Nos. 184/166

MTC 3.1.3 0.9

,L 0.8 a

0

_0.7 0

4-co 0.7 bd 0

a)

-0 0.6 6,0.

0~

a CD

-. 2 L.

C 0.3

~0.

I-0 0 0.2 0

0 10 20 30 40 50 60 70 80 90 100 PERCENT RTP Figure 3.1.3-1 (page 1 of 1)

Moderator Temperature Coefficient vs. Power Level McGuire Units and 2 3.1 .3-3 Amendment Nos. 184/166

Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with all individual indicated rod positions within 12 steps of their group step counter demand position.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) A.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months untrippable. limit specified in the COLR.

OR A.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND A.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (continued)

McGuire Units 1 and 2 3.1 .4-1 Amendment Nos. 184/166

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One rod not within B.1 Restore rod to within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months alignment limits. alignment limits.

OR B.2.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limit specified in the COLR.

OR B.2.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND B.2.2 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to < 75% RTP.

AND B.2.3 Verify SDM is within the Once per limit specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B.2.4 Perform SR 3.2.1.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

(continued)

McGuire Units 1 and 2 3.1 .4-2 Amendment Nos. 184/166

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not met.

D. More than one rod not D.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit. limit specified in the COLR.

OR D.1.2 Initiate boration to restore required SDM to within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limit.

AND D.2 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod position deviation monitor is inoperable (continued)

McGuire Units 1 and 2 3.1 .4-3 Amendment Nos. 184/166

Rod Grou'p Alignment Limits 3.1.4 SUIRVF I __ _z I ANCF REQjIREMENT Intiue I_ .. \W_ -- I SURVEILLANCE FREQUENCY SR 3.1.4.2 Verify rod freedom of movement (trippability) by moving 92 days each rod not fully inserted in the core > 10 steps in either direction. OR Prior to entering MODE 3 upon Unit 1 startup following the Unit 1 End of Cycle 13 refueling outage)

SR 3.1.4.3 Verify rod drop time of each rod, from the fully withdrawn Prior to reactor position, is < 2.2 seconds from the beginning of decay of criticality after stationary gripper coil voltage to dashpot entry, with: each removal of the reactor head

a. Ta, > 551IF; and

b. All reactor coolant pumps operating.

One time change applicable to Unit I only I

McGuire Units 1 and 2 3.1.4-4 Amendment Nos. 186 (Unit 1) 167 (Unit 2)

Shutdown Bank Insertion Limits 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.5 Each shutdown bank shall be within insertion limits specified in the COLR.

APPLICABILITY: MODE 1, MODE 2 with any control bank not fully inserted.

This LC -isnoaplNOTE--- werm S34 This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months banks not within limits. limit specified in the COLR.

OR A.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND A.2 Restore shutdown banks to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.1 .5-1 Amendment Nos. 184/166

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the limits specified in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the COLR.

McGuire Units 1 and 2 3.1 .5-2 Amendment Nos. 184/166

Control Bank Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Control Bank Insertion Limits LCO 3.1.6 Control banks shall be within the insertion, sequence, and overlap limits specified in the COLR.

APPLICABILITY: MODE 1, MODE 2 with kf > 1.0.

UI t- -_-_--_--_

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Control bank insertion A.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limits not met. limit specified in the COLR.

OR A.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND A.2 Restore control bank(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within limits.

(continued)

McGuire Units 1 and 2 3.1 .6-1 Amendment Nos. 184/166

Control Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Control bank sequence B.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or overlap limits not met. limit specified in the COLR.

OR B.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND B.2 Restore control bank 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months sequence and overlap to within limits.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is within the Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months limits specified in the COLR. prior to achieving criticality (continued)

McGuire Units 1 and 2 3.1 .6-2 Amendment Nos. 184/166

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the limits 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months specified in the COLR.

AND Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod insertion limit monitor is inoperable SR 3.1.6.3 Verify sequence and overlap limits specified in the COLR 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months are met for control banks not fully withdrawn from the core.

McGuire Units 1 and 2 3.1 .6-3 Amendment Nos. 184/166

Rod Position Indication 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication LCO 3.1.7 The Digital Rod Position Indication (DRPI) System and the Demand Position Indication System shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

a ------ -------

1IT 1r%1-f-IN[" I Separate Condition entry is allowed for each inoperable rod position indicator per group and each demand position indicator per bank.

CONDITION REQUIRED ACTION COMPLETION TIME A. One DRPI per group A.1 Verify the position of the Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for one or rods with inoperable more groups. position indicators by using movable incore detectors.

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

B. One or more rods with B.1 Verify the position of the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable position rods with inoperable indicators have been position indicators by using moved in excess of movable incore detectors.

24 steps in one direction since the last OR determination of the rod's position. B.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to < 50% RTP.

(continued)

McGuire Units 1 and 2 3.1 .7-1 Amendment Nos. 184/166

Rod Position Indication 3.1.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One demand position C.1.1 Verify by administrative Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months indicator per bank means all DRPIs for the inoperable for one or affected banks are more banks. OPERABLE.

AND C.1.2 Verify the most withdrawn Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months rod and the least withdrawn rod of the affected banks are

< 12 steps apart.

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

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the group Once prior to demand position for the full indicated range of rod travel. criticality after each removal of the reactor head McGuire Units 1 and 2 3.1 .7-2 Amendment Nos. 184/166

PHYSICS TESTS Exceptions 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PHYSICS TESTS Exceptions LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of LCO 3.1.3, Moderator Temperature Coefficient (MTC)";

LCO 3.1.4, Rod Group Alignment Limits";

LCO 3.1.5, Shutdown Bank Insertion Limits";

LCO 3.1.6, Control Bank Insertion Limits'; and LCO 3.4.2, RCS Minimum Temperature for Criticality' may be suspended, provided:

a. RCS lowest loop average temperature is > 541 F; and

b. SDM is within the limit specified in the COLR.

APPLICABILITY: MODE 2 during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore 15 minutes SDM to within limit.

AND A.2 Suspend PHYSICS TESTS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months exceptions.

B. THERMAL POWER not B.1 Open reactor trip breakers. Immediately within limit.

C. RCS lowest loop C.1 Restore RCS lowest loop 15 minutes average temperature not average temperature to within limit. within limit.

(continued)

McGuire Units and 2 3.1 .8-1 Amendment Nos. 184/166

PHYSICS TESTS Exceptions 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

' D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATIONAL TEST on power Prior to initiation of range and intermediate range channels per SR 3.3.1.7, PHYSICS TESTS SR 3.3.1.8, and Table 3.3.1-1.

SR 3.1.8.2 Verify the RCS lowest loop average temperature is 30 minutes

> 541 'F.

SR 3.1.8.3 Verify THERMAL POWER is < 5% RTP. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SR 3.1.8.4 Verify SDM is within the limit specified in the COLR. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months McGuire Units and 2 3.1 .8-2 Amendment Nos. 184/166

Fo(X,Y,Z) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (Fo(X,Y,Z))

LCO 3.2.1 Fm.(X,Y,Z) shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. FM (X,Y,Z) not within A.1 Reduce THERMAL 15 minutes steady state limit. POWER > 1% RTP for each 1% Fa(XYZ) exceeds limit.

AND A.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Neutron Flux-High trip setpoints > 1% for each 1%

Fma(X,Y,Z) exceeds limit.

AND A.3 Reduce Overpower AT trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months setpoints > 1% for each 1% Fm(X,Y,Z) exceeds limit.

AND A.4 Perform SR 3.2.1.1, SR Prior to increasing 3.2.1.2, and SR 3.2.1.3. THERMAL POWER above the limit of Required Action A.1 (continued)

McGuire Units 1 and 2 3.2.1 -1 Amendment Nos. 184/166

Fa(X,Y,Z) 3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Fm(X,Y,Z) > B.1 Reduce AFD limits > 1% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months FL (X,Y,Z)OP. from COLR limits for each 1% Fma(X,Y,Z) exceeds limit.

AND B.2 Adjust F(X,Y,Z)0 P by the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months percent reduction in AFD.

C. Fm,(X,Y,Z) > C.1 Reduce the OTAT Trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months FL(X,Y,Z)RPS. Setpoint from COLR limit by KSLOPE for each 1%

F(X,Y,Z) exceeds limit.

AND C.2 Adjust FLo(XY,Z)RPs by the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months equivalent reduction in OTAT trip setpoint.

D. Required Action and D.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.2.1 -2 Amendment Nos. 184/166

Fo(XYZ) 3.2.1 SURVEILLANCE REQUIREMENTS

_ ^ ----------- a--NI OTE---- - --------

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

SURVEILLANCE FREQUENCY 4

SR 3.2.1.1 Verify F.(X,Y,Z) is within steady state limit. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by

> 10% RTP, the THERMAL POWER at which F (X,Y,Z) was last verified AND 31 EFPD thereafter (continued)

McGuire Units 1 and 2 3.2.1-3 Amendment Nos. 184/166

Fo(XY.Z) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 4

SR 3.2.1.2 ------ --- NOTE------ -- _

Extrapolate F1(X,Y,Z) using at least two measurements to 31 EFPD beyond the most recent measurement. If F' (X,Y,Z) is within limits and the 31 EFPD extrapolation indicates:

Fm,(X.YZ)EXTRAPOLATED > F'(X,Y,Z) EXTRAPOLATED.

and EOX.-Y.Z)EXTRAPOLATED > (X.Y.Z)

FO(XY-Z) 0 EXTRAPOLATED F0(XYZ) then:

a. Increase Fm (X,Y,Z) by the appropriate factor specified in the COLR and reverify Fm (X,Y,Z) < FL (X,YZ)OP; or

b. Repeat SR 3.2.1.2 prior to the time at which Fm (X,Y,Z) 5 F$(X,Y,Z) 0 is extrapolated to not be met.

2. Extrapolation of Fm (X,Y,Z) is not required for the initial flux map taken after reaching equilibrium conditions.

Verify F' (X,Y,Z) < FL(X,Y,Z)OP. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by >

10% RTP, the THERMAL POWER at which F..(X,Y,Z) was last verified AND 31 EFPD thereafter I (continued)

McGuire Units 1 and 2 3.2.1-4 Amendment Nos. 188 (Unit 1) 169 (Unit 2)

FO(X,Y,Z)

. 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 4

SR 3.2.1.3 Nitj t E _ _ A ______

1. Extrapolate FIA(X,Y,Z) using at least two measurements to 31 EFPD beyond the most recent measurement. If F" (X,Y,Z) is within limits and the 31 EFPD extrapolation indicates:

F (XYZ)EXTRAPOLATED > FL(XYZ)PSEXTRAPOLATED, and E (X.Y.Z)EXTRAPOLATED > Fm (X.Y.Z)

FK(XY,Z)PSEXTRAPOLATED FL(XYZ)RPS then:

a. Increase F' (X,Y,Z) by the appropriate factor specified in the COLR and reverify Fm (X,Y,Z) < F(X,YZ)RPS ; or

b. Repeat SR 3.2.1.3 prior to the time at which Fm (X,Y,Z) < FL (X,Y,Z)RP is extrapolated to not be met.

2. Extrapolation of Fmo(X,Y,Z) is not required for the initial flux map taken after reaching equilibrium conditions.

Verify Fmo(X,Y,Z) < F.(XYZ) Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by >

10% RTP, the THERMAL POWER at which Fm (X,Y,Z) was last verified AND 31 EFPD thereafter McGuire Units 1 and 2 3.2.1-5 Amendment Nos. 188 (Unit 1) 169 (Unit 2)

FaH(X,Y) 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (Fm(X,Y))

LCO 3.2.2 Fm(X,Y) shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. - NOTE- A.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Required Actions A.3.2.2 POWER > RRH% from and A.4 must be RTP for each 1% F"'H(X,Y) completed whenever exceeds limit.

Condition A is entered.

AND FmOH not within limit. A.2.1 Restore Fm'(X,Y) to within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months limit for RTP.

OR A.2.2 Reduce Power Range 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Neutron Flux-High trip setpoints > RRH% for each 1% Fym,,(X,Y) exceeds limit.

AND A.3.1 Restore Fm'&H (XY) to within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months limit for RTP.

OR A.3.2.1 Reduce OTAT Trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Setpoint by > TRH for each 1% Fmm(X,Y) exceeds limit.

AND (continued)

McGuire Units 1 and 2 3.2.2-1 Amendment Nos. 184/166

FX(X,Y) 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.2.2Perform SR 3.2.2.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND A.4 ------ NOTE-------

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

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER reaching > 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.2.2-2 Amendment Nos. 184/166

Fm(X,Y) 3.2.2 SURVEILLANCE REQUIREMENTS

_----------------~--------NOTE ---- ---- ---- ----- ------ ---- ----------- ~

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

SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify FMH(X,Y) is within steady state limit. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by >

10% RTP, the THERMAL POWER at which FMH(XY) was last verified AND 31 EFPD thereafter (continued)

McGuire Units 1 and 2 3.2.2-3 Amendment Nos. 184/166

F.H(XY) 3.2.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE . FREQUENCY SR 3.2.2.2 -NOTES-

1. Extrapolate FH(X,Y) using at least two measurements to 31 EFPD beyond the most recent measurement. If FMH(XY) is within limits and the 31 EFPD extrapolation indicates:

F (X,Y)EXTRAPOLATED > FL H(XY)SURVEXTRAPOLATED and E aH(X.Y)EXTRAPOLATED > E'MH(X.Y) rL VVySURV eL yv vSURV FAHV"'J EXTRAPOLATED FaHV"'J then:

a. Increase FM H(X,Y) by the appropriate factor specified in the COLR and reverify FMAH (XY) < FLH (X,Y)SURV; or

b. Repeat SR 3.2.2.2 prior to the time at which FMAH (XY) ' FL H(X,Y)SURV is extrapolated to not be met.

2. Extrapolation of FM H(X,Y) is not required for the initial flux map taken after reaching equilibrium conditions.

Verify FMAH (X,Y) F*) ) Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by >

10% RTP, the THERMAL POWER at which F ,H(XY) was last verified AND 31 EFPD thereafter McGuire Units 1 and 2 3.2.2-4 Amendment Nos. 188 (Unit 1) 169 (Unit 2)

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)

LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.

___________- --- n" I--- -

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore 7 days channel.

AND Once within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter with the AFD monitor alarm inoperable McGuire Units 1 and 2 3.2.3-1 Amendment Nos. 184/166

QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be < 1.02.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP.

I It :- - - - _ _ _ _ _ _ _ _ _ _ _

Not applicable until calibration of the excore detectors is completed subsequent to refueling.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. QPTR not within limit. A.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER > 3% from RTP for each 1% of QPTR

> 1.02.

AND A.2 Perform SR 3.2.4.1 and Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reduce THERMAL POWER > 3% from RTP for each 1% of QPTR >

1.02.

AND A.3 Perform SR 3.2.1.1 and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.2.2.1.

AND Once per 7 days thereafter AND (continued)

McGuire Units 1 and 2 3.2.4-1 Amendment Nos. 184/166

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Neutron Flux - High Trip Setpoint > 3% for each 1%

of QPTR > 1.02.

AND A.5 Reevaluate safety Prior to increasing analyses and confirm THERMAL POWER results remain valid for above the more duration of operation under restrictive limit of this condition. Required Action A.1 or A.2 AND A.6 ------ -- NOTE Perform Required Action A.6 only after Required Action A.5 is completed.

Calibrate excore detectors Prior to increasing to show zero QPT. THERMAL POWER above the more restrictive limit of Required Action A.1 or A.2 AND (continued)

___________________________________ 1 McGuire Units 1 and 2 3.2.4-2 Amendment Nos. 184/166

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.7 NOTE-----

Required Action A.7 must be completed when Required Action A.6 is completed.

Perform SR 3.2.1.1 and Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.2.1. reaching RTP OR Within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the more restrictive limit of Required Action A.1 or A.2 B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to < 50% RTP.

Time not met.

McGuire Units 1 and 2 3.2.4-3 Amendment Nos. 184/166

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ---- - -- NOTES----------------

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER

<75% RTP, the remaining three power range channels can be used for calculating QPTR.

2. SR 3.2.4.2 may be performed in lieu of this Surveillance.

Verify QPTR is within limit by calculation. 7 days AND Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter with the QPTR alarm inoperable SR 3.2.4.2 ---------- -NOTES------- ---

Only required to be performed if input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER > 75% RTP.

Verify QPTR is within limit using the movable incore 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months detectors.

McGuire Units 1 and 2 3.2.4-4 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1.

ACTIONS Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more referenced in Table 3.3.1-1 required channels for the channel(s).

inoperable.

B. One Manual Reactor B.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Trip channel inoperable. OPERABLE status.

OR B.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months C. One channel or train C.1 Restore channel or train to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

OR C.2 Open reactor trip breakers 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months (RTBs).

(continued)

McGuire Units 1 and 2 3.3.1 -1 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One channel inoperable. ----------- --- -NOTE---- ----

One channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing and setpoint adjustment.

_ ~~ ~ ~ ~ - - -- - --- ---

D.1.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND D.1.2 Reduce THERMAL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months POWER to < 75% RTP.

OR D.2.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND

NOTE-------

Only required to be performed when the Power Range Neutron Flux input to QPTR is inoperable.

D.2.2 Perform SR 3.2.4.2. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR D.3 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

McGuire Units 1 and 2 3.3.1 -2 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 ACTIONS (continued) _

CONDITION REQUIRED ACTION COMPLETION TIME E. One channel inoperable. ---------------- NOTE----------------

One channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

E.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR E.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. THERMAL POWER F.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

> P-6 and < P-10, one POWER to < P-6.

Intermediate Range Neutron Flux channel OR inoperable.

F.2 Increase THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to > P-1 0.

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

Limited boron concentration changes associated with RCS inventory control or limited plant temperature changes are allowed.

G. THERMAL POWER G.1 Suspend operations Immediately

> P-6 and < P-1 0, two involving positive reactivity Intermediate Range additions.

Neutron Flux channels inoperable. AND G.2 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to < P-6.

H. THERMAL POWER H.1 Restore channel(s) to Prior to increasing

< P-6, one or two OPERABLE status. THERMAL POWER Intermediate Range to > P-6 Neutron Flux channels inoperable.

(continued)

McGuire Units 1 and 2 3.3.1-3 Amendment Nos. 216 & 197

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

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

Limited boron concentration changes associated with RCS inventory control or limited plant temperature changes are allowed.

I. One Source Range 1.1 Suspend operations Immediately Neutron Flux channel involving positive reactivity inoperable. additions.

J. Two Source Range J.1 Open RTBs. Immediately Neutron Flux channels inoperable.

K. One Source Range K.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Neutron Flux channel OPERABLE status.

inoperable.

OR K.2 Open RTBs. 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months

NOTES-------

Plant temperature changes are allowed provided that SDM is maintained and Keff remains <

0.99.

L. Required Source Range L.1 Suspend operations Immediately Neutron Flux channel involving positive reactivity inoperable. additions.

AND L.2 Close unborated water 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months source isolation valves.

AND L.3 Perform SR 3.1.1.1. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter (continued)

McGuire Units 1 and 2 3.3.1 -4 Amendment Nos.216 & 197

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME M. One channel inoperable. NOTE--------

One channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

M.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR M.2 Reduce THERMAL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months POWER to < P-7.

N. One Reactor Coolant -------NOTE -----

Flow - Low (Single One channel may be bypassed for Loop) channel up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance inoperable. testing.

N.A Place channel In trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR N.2 Reduce THERMAL 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months POWER to < P-8.

(continued)

McGuire Units 1 and 2 3.3.1 -5 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

0. One Turbine Trip - Low -- -- NOTE--- ---

Fluid Oil Pressure One channel may be bypassed for channel inoperable. up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

0.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR 0.2 Reduce THERMAL 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months POWER to < P-8.

P. One or more Turbine P.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Trip - Turbine Stop Valve Closure channels OR inoperable.

P.2 Reduce THERMAL 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months POWER to < P-8.

Q. One train inoperable. ----- NOTE One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

0.1 Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

OR Q.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

McGuire Units 1 and 2 3.3.1 -6 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME R. One RTB train NOTES----

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

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

R.1 Restore train to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

OR R.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months S. One or more channel(s) S.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. required state for existing unit conditions.

OR S.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months (continued)

McGuire Units 1 and 2 3.3.1-7 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME T. One or more channel(s) T.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. required state for existing unit conditions.

OR T.2 Be in MODE 2. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months U. One trip mechanism U.1 Restore inoperable trip 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable for one RTB. mechanism to OPERABLE status.

OR U.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months V. Two RTS trains V.1 Enter LCO 3.0.3. Immediately inoperable.

McGuire Units 1 and 2 3.3.1 -8 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2 ----------------- -NOTES -------------

1. Adjust NIS channel if absolute difference is > 2%

RTP.

2. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is > 15% RTP.

Compare results of calorimetric heat balance calculation 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to Nuclear Instrumentation System (NIS) channel output.

SR 3.3.1.3 -------------------NOTES----- -

1. Adjust NIS channel if absolute difference is > 3%

AFD.

2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is > 15% RTP.

Compare results of the incore detector measurements to 31 effective full NIS AFD. power days (EFPD)

(continued)

McGuire Units 1 and 2 3.3.1-9 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 -------------NOTES-----

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.

Perform TADOT. 31 days on a STAGGERED TEST BASIS SR 3.3.1.5 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.1.6 ----- NOTES---------- -

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is > 75% RTP.

Calibrate excore channels to agree with incore detector 92 EFPD measurements.

SR 3.3.1.7 --------- NOTES-----

Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.

Perform COT. 92 days (continued)

McGuire Units 1 and 2 3.3.1 -10 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.8 This Surveillance shall include verification that interlocks P-6 (for the Intermediate Range channels) and P-10 (for the Power Range channels) are in their required state for existing unit conditions.

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

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

McGuire Units 1 and 2 3.3.1-1 1 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.9 - ------- ----- ---- -------

Verification of setpoint is not required.

Perform TADOT. 92 days SR 3.3.1.10 ------ ----- NOTES-----

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

Perform CHANNEL CALIBRATION. 18 months SR 3.3.1.11 --- ----------- NOTES-

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Power and Intermediate Range Neutron Flux detector plateau voltage verification is not required to be performed prior to entry into MODE 1 or2.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.1.12 Perform CHANNEL CALIBRATION. 18 months SR 3.3.1.13 Perform COT. 18 months (continued)

McGuire Units 1 and 2 3.3.1 -12 Amendment Nos. 1841166

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.14 ---------------------- NOTES---------------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.1.15 ------- NOTES---------- ------- NOTE---

Verification of setpoint is not required. Only required

- --- - ----- when not performed within previous 31 days Perform TADOT. Prior to reactor startup SR 3.3.1.16 ---------- ----- NOTES---- --------------

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits. 18 months on a STAGGERED TEST BASIS SR 3.3.1.17 Verify RTS RESPONSE TIME for RTDs is within limits. 18 months McGuire Units and 2 3.3.1 -13 Amendment Nos. 184/166

RTS Instrumentation 3.3.1 Table 3.3.1 -1 (page of 7)

Reactor Tnp Systern Instrurnentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDmONS CHANNELS CONDONS REQUIREMENTS VALUE SETPOINT I

1. Manual Reactor Trip 1,2 8 SR 3.3.1.14 NA NA 3(a) 4a), (8) 2 C SR 3.3.1.14 NA NA

2. Power Range Neutron Flux

a. Hgh 1.2 4 D SR 3.3.1.1 :S1IC%RTP 109% RTP I SR 33.1.2 SR 33.1.7 SR 3.3.1.1 SR 33.1.16

b. Low 4 E SR 3.3.1.1 S 26% RTP 25% RTP SR 3.3.1.8 SR 33.1.11 SR 33.1.16

3. Power Range Neuton Flux Rate I

High Positive Rate 1.2 4 D SR 331.7 5.5% RTP 5%RTP SR 3.3.1.11 wit trne wlt tirne constah 2ac k2 s

4. tenedlate Range 2 F.G SR 3.3.1.1 25% RTP I 1 (b). 2 (c)

Neutron Flux SR33.1.8 SR 3.3.1.11 2 (d) 2 H SR 3.3.1.1 £S30% RTP 25% RTP I SR 33.1.8 SR 33.1.11

5. Source Range 2 (d) 2 L.J SR 3.3.1.1 :113E0cps J.OE5 cps I Neutron Fl SR 3Zt.3 SR 33t.1.1 1.0 ES cps I 3 (a) 4(a), 5 (a) 2 J.K SR 33.1.1 S1WE5 SR 33.1.7 SR 3.3.1.11 3(0).4(0) 1),6 L SRS.3.1.1 NIA WA SR 33.1.1 1 (a) W11 PAMr Trip Orakam (RTBa) dosed and Rod Cctd System capable of rod ,wftfdv*L (b) Belw We P.10 (Por Rang. Neutron Fhkn hImocb.

(C) Above Ie P48 (Irmactds Range Neutrn FluRc Wtado (d) Below the P-0 (ntmU eRange Neuton Flu) kItedoIa (s) Wthl open. h RFleT condWon, sou ng Fw on dos rt povd raertrip but does pro de I ration.

McGuire Units 1 and 2 3.3.1-14 Amendment Nos. 194/175

RTS Instrumentation 3.3.1 Table 3.3. 11 (page 2 of 7)

Reactor Trip Syste Istrnumentation APPLICABLE MODES OR OTHER NOMINAL I SPECIFIED REOUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDmONS REQUIREMENTS VALUE SETP0Kr

6. Oertreprature AT 1,2 4 E SR 3.1.1 Refer to Refer to SR 3.3.1.3 Note 1 (page Note I SR 33.1.6 3.3.1.18) (Page SR 3.3.1.7 3.3.1.18)

SR 3.3.1.12 SR 3.3.1.16 SR 3.3.1.17

7. Overpower AT 1.2 4 E SR 3.3.1.1 Refer lo Refer to SR 3..1.3 Noe 2 (Page Note 2 SR 3.3.1.6 3.3.1-19) (Page SR 3.3.1.7 33.1.19)

SR 3.3.1.12 SR 3.3.1.16 SR 33.1.17

8. Purizer Pressure

a. Low 4 M SR 3.3.1.1 2:1 MS psig l94S psig I SR 3.3.1.7 SR 3.3.1.10 SR 33.1.16

b. Hih 1.2 4 E SR33.1.1 :12395 P61g 2385 1g SR 3.3.1.7 SR 3.3.1.10 SR 3.31.16 O.. Pressurizer Water I) 3 M SR331.1 93% 92% 1 Level *High SR 3.3.1.7 SR 3.3.1.10

10. ReorCoolantFlow.

LOw

a. SigI Loop 1 3 per loop N SR 3=1.1 91% I SR 3.31.7 SR 3.1.10 SR 3.3.1.16

b. Two LoP I (h) 3 per 110p M SR 3.31.1 91% I SR 33.1.7 SR 3..1.10 SR 3.3.1

11. Unwvote RCP* t perb M SR 3.&1.9 XU0l6V 506V I SR 3.1.10 SR 3.1.16 (1) Aboe O P.7 (LQ Pmr RArTr4s Bkod) hiloocF.

(g) Abov 3wP4 (Poer Rng Neutvn Flwc terock.

(h) Above #w P-7 (Low Powr Reacor Trips Sod) tedoolAurd below ft P48 (Powr Range NAon FI) hbkec McGuire Units and 2 3.3.1-15 Amendment Nos. 194/175

RTS Instrumentation 3.3.1 Table 3.3.1 1 (page 3 of 7)

Reactor Trip System Instnmentation APPLICABLE MODES OR OTHER NOMINAL FUNCTION

12. Underfrequency SPECIFIED CONDITIONS t (t)

REQUIRED CHANNELS 1 per bus CONDiTIONS M

SURVEILLANCE REQUIREMENTS SR 3.3.1.9 ALLOWABLE VALUE a 55.9 Hz TRIP SETPOINT 56.4 Hz I

RCPs SR 3.3.1.10 SR 3.3.1.16

13. Stearn Generator 1.2 4perSG E SR 3.3.1.1 > 15% 16.7%

(SG) Wat Level - SR 3.3.1.7

. Low Low SR 33.1.10 SR 3.3.1.16

14. Turbine Trip

a. Low Fid Ol 1(9) 3 0 SR 3.3.1.10 > 42 psig 45 psig I Pressure SR 3.3.1.15

b. Tubie Sp 1(9) 4 P SR3.3.1.10 Z 1%open > 1%open Valve Closue SR 3.3.1.15

15. Safety Injection (SI) 1.2 2 trains a SR 3.3.1.5 NA NA Input Iron Engineered SR 3.3.1.14 Safety Feahr Actuation System (ESFAS)

16. Reactor Trip System Interocks

a. Intermediate 2 (d) 2 S SR 3.3.1.11 >4E-11 amp IE-10amp I Range Neutron SR 3.3.1.13 Flux. P4 NA

b. Low Power 1 1per train T SR 3.3.1.5 NA Reactor Trips Bkoc. P-7

c. Power Range 1 4 T SR 3.3.1.11 49% R TP 48% RTP I Neuton Fkm SR 33.1.13 P.8

d. P0weRange 1.2 4 S SR 3..1 Z 7% RTP 10% RTP I Neuon Fkm SR 3.l1.13 and I 11%

P.10 RTIP

a. Turbine hIruse 2 T SR 3.31.12 .clIl% tubine 10C% turbine Pesr. P-13 SR 33.1.13 knF-l (coninued)

(d) Below VW P-6 (Itrmedate Rae Neuton Flux) trocks.

() Above #* P 7 (Low Power RePr Trip Bck) t .

() Above to P8 Power Re Nutn Flux) Inltok.

McGuire Units 1 and 2 3.3.1 -16 Amendment Nos. 194/175

RTS Instrumentation 3.3.1 Table 3.3.1 1 (page 4 o 7)

Reactor Trip System Instrumentation APPUCABLE MODES OR OTHER NOMINAL I SPECIFIED REOUIRED SURVEILLANCE ALLOWABLE TRIPI FUNCTION CONDmONS CHANNELS CONDmONS REQUIREMENTS VALUE SETPOINTI

17. Reactor Trip 1,2 2 trains R.V SR3.3.1.4 NA NA Bmakersa) 3(9), 41), (8) 2 trains C SR 3.3.1.4 NA NA

18. ReactorTrip Breaker 1.2 1 each per U SR 3.3.1.4 NA NA Undervollge and RTB Shunt Trip Mchls 3(8), 4 (a), 5 (a) 1 each per C SR 31.4 NA NA RTB, I9. Autialic Trip Logic 1,2 2 trahs a, v SR 3.3.1.5 NA NA 3(a), 4a) 5a) 2 trans C SR 3.3.1.5 NA NA (a) With RTBs closd and Rod Control System capable of rod whdrawal.

(i) kickdrg any ractor trip bypass breakers that are racked In and closed for bypassing an RTB.

McGuire Unfts 1 and 2 3.3.1-17 Amendment Nos. 194/175

F-TS nstrunenatiorn 3.3.1 Table 3.3.1-1 (page 5 of 7)

Reactor Trip System Instrumentation Note 1: Overtemperature AT The Overtemperature AT Function Allowable Value shall not exceed the following NOMINAL TRIP SETPOINT by more than 4.3%O of RTP.

AT ( ) 1 ))ATK - K)I (1 4 T (

-K )1 +3 (P P 1)N 1+rS)

(1+r~s) (1+ r5 s) (1-r T6 S)

Where: AT is measured RCS AT by loop narrow range RTDs, CF.

ATo is the indicated AT at RTP, F.

s is the Laplace transform operator, sec-1.

T is the measured RCS average temperature, F.

T' is the nominal Tavg at RTP, < 585.1 F.

P is the measured pressurizer pressure, psig P' is the nominal RCS operating pressure, = 2235 psig K, = Overtemperature AT reactor NOMINAL TRIP SETPOINT, as presented in the COLR, K2 = Overtemperature AT reactor trip heatup setpoint penalty coefficient, as presented in the COLR, K3 = Overtemperature AT reactor trip depressurization setpoint penalty coefficient, as presented in the COLR,

.tl2 = Time constants utilized in the lead-lag controller for AT, as presented in the COLR, t3 = Time constants utilized in the lag compensator for AT, as presented in the COLR, T4, 5 = Time constants utilized in the lead-lag controller for Tavg, as presented in the COLR, T6 = Time constants utilized in the measured Tavg lag compensator, as presented in the COLR, and, f1(Al) = a function of the indicated difference between top and bottom detectors of the power-range nuclear ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that:

(i) for qt - qt between the "positive" and "negative" fI(Al) breakpoints as presented in the COLR; f (Al) = 0, where q, and qb are percent RATED THERMAL POWER in the top and bottom halves of the core respectively, and qt + qb is total THERMAL POWER in percent of RATED THERMAL POWER; (continued)

McGuire Units and 2 3.3.1 -18 Amendment Nos. 202/183

RTS nstrumnertation 3.3.1 Table 3.3.1-1 (page 6 of 7)

Reactor Trip System Instrumentation (ii) for each percent imbalance that the magnitude of q - qt. is more negative than the f(Al) "negative" breakpoint presented in the CCLR, the AT Trip Setpoint shall be automatically reduced by the f1(Al) "negative" slope presented in the COLR; and (iii) for each percent imbalance that the magnitude of q - , is more positive than the f(Al) "positive" breakpoint presented in the COLR, the AT Trip Setpoint shall be automatically reduced by the f(AI)

"positive" slope presented in the COLR.

Note 2: Overpower AT The Overpower AT Function Allowable Value shall not exceed the following NOMINAL TRIP SETPOINT by more than 2.6% of RTP.

AT 1Ts)isJM {TK4 -K 5 jS (+ jT-K6 [Ti sT]-f2 ()}

A(1 + T2 5) ( 1 ) I~K4- 1 + r7 + 6 S) [ + r6 Where: AT is measured RCS AT by loop narrow range RTDs, F.

ATo is the indicated AT at RTP, F.

s is the Laplace transform operator, sec '.

T is the measured RCS average temperature, 0F.

T is the nominal Tavg at RTP, < 585.1 F.

K4 = Overpower AT reactor NOMINAL TDIP SETPOINT as presented in the COLR, K5 = 0.02/0F for increasing average temperature and 0 for decreasing average temperature, K6 = Overpower AT reactor trip heatup setpoint penalty coefficient as presented in the COLR for T > T and K6= 0 for T < T, Tl, T2 = Time constants utilized in the lead-lag controller for AT, as presented in the COLR,

¶3 = Time constants utilized in the lag compensator for AT, as presented in the COLR, T6 = Time constants utilized in the measured Tavg lag compensator, as presented in the COLR, T7 = Time constant utilized in the rate-lag controller for Tavg, as presented in the COLR, and f2(AI) = a function of the indicated difference between top and bottom detectors of the power-range nuclear ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that:

(continued)

McGuire Units 1 and 2 3.3.1 -19 Amendment Nos. 202/183

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 7 of 7)

Reactor Trip System Instrumentation (i) for qt - qb between the positive' and negative" f2(AI) breakpoints as presented in the COLR; f2(AI) = 0, where qt and qb are percent RATED THERMAL POWER in the top and bottom halves of the core respectively, and qt + qb is total THERMAL POWER in percent of RATED THERMAL POWER; (ii) for each percent imbalance that the magnitude of qt - qb is more negative than the f 2(AI) "negative breakpoint presented in the COLR, the AT Trip Setpoint shall be automatically reduced by the f2(A1) negative' slope presented in the COLR; and (iii) for each percent imbalance that the magnitude of qt - qb is more positive than the f2(AI) positive' breakpoint presented in the COLR, the AT Trip Setpoint shall be automatically reduced by the f2(AI)

"1positive" slope presented in the COLR.

McGuire Units 1 and 2 3.3.1-20 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2-1.

ACTIONS

_------NOTIt--- --- ___ ___

Separate Condition entry is allowed for each Function.

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

B. One channel or train B.1 Restore channel or train to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

OR B.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND B.2.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

McGuire Units 1 and 2 3.3.2-1 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One train inoperable. C.1 ------ NOTE---------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

OR C.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND C.2.2 Be in MODE 5. 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months D. One channel inoperable. D.1 -------NOTE------

One channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR D.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND D.2.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months (continued)

McGuire Units 1 and 2 3.3.2-2 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One Containment E.1 ----- NOTE-----

Pressure channel One additional channel inoperable. may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

Place channel in bypass. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR E.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND E.2.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months F. One channel or train F.1 Restore channel or train to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

OR F.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND F.2.2 Be in MODE 4. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months G. One Steam Line G.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Isolation Manual OPERABLE status.

Initiation - individual channel inoperable. OR G.2 Declare associated steam 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months line isolation valve inoperable.

(continued)

McGuire Units 1 and 2 3.3.2-3 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. One train inoperable. H.1 N TE-----NOTE-------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

OR H.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND H.2.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months I. One train inoperable. 1.1 --------NOTE-------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

OR 1.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

McGuire Units 1 and 2 3.3.2-4 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. One channel inoperable. J.1 - --------NOTE ------

One channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR J.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months K. One Main Feedwater K.1 Place channel in trip. 1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Pumps trip channel inoperable. OR K.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months L. One required channel in L.1 Restore the inoperable 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months one train of Doghouse train to OPERABLE status.

Water Level-High High inoperable. OR L.2 Perform continuous 73 hours8.449074e-4 days 0.0203 hours 1.207011e-4 weeks 2.77765e-5 months monitoring of Doghouse water level.

M. Two trains of Doghouse M.1 Perform continuous 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Level-High High monitoring of Doghouse inoperable. water level.

(continued)

McGuire Units 1 and 2 3.3.2-5 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

. . . .~~~~~~~~~~~~~~~~~~~~~~~~~~

CONDITIONS REQUIRED ACTION COMPLETION TIME N. One or more channels of N.1 Restore channel(s) to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Auxiliary Feedwater OPERABLE status.

Suction Pressure-Low for one auxiliary OR feedwater pump inoperable. N.2 Declare associated 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months auxiliary feedwater pump inoperable.

O. One or more channels of 0.1 Declare associated Immediately Auxiliary Feedwater auxiliary feedwater pumps Suction Pressure-Low inoperable.

for two or more auxiliary feedwater pumps inoperable.

P. One channel inoperable. P.1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND P.2 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OPERABLE status.

.~ ___________________ (continued)

McGuire Units 1 and 2 3.3.2-6 Amendment Nos. 198/179

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Q. One channel inoperable. Q.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months required state for existing unit condition.

OR Q.2.1 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND Q.2.2 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months R. One or more R.1 Declare affected supported Immediately Containment Pressure system inoperable.

Control System channel(s) inoperable.

S. Required Action and S.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition P not AND met.

S.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.3.2-7 Amendment Nos. 198/179

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS

---------------NOTE--- ---- ----------- - -- ------- - ---- __

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

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.2.2 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.2.3 Perform COT. 31 days SR 3.3.2.4 Perform MASTER RELAY TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.2.5 Perform COT. 92 days SR 3.3.2.6 Perform SLAVE RELAY TEST. 92 days SR 3.3.2.7 ------------ -------

Verification of setpoint not required for manual initiation functions.

Perform TADOT. 18 months (continued)

McGuire Units 1 and 2 3.3.2-8 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.8 ------- ------------ NOTE-This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.2.9 --------------- NOTE----

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is > 900 psig.

Verify ESFAS RESPONSE TIMES are within limit. 18 months on a STAGGERED TEST BASIS McGuire Units 1 and 2 3.3.2-9 Amendment Nos. 184/166

ESFAS Instrumentation 3.3.2 Table 3.32-1 (page 1 of 6)

Engineered Safety Featue Actuation Systern Instrumentaton APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDrONS CHANNELS CONDmONS REOUIREMENTS VALUE SETPOINT

1. Sat ion

a. ManuL Iniftbon 1,2.3.4 2 8 SR 327 NA NA

b. Automatic 1,2.3.4 2 bals C SR 3.32.2 NA NA Achetoton Logic SR 3.32.4 and Acuation SR 3.32.6 Relays

c. Contakwm~i 3 D SR 3.32.1 S 12psig 1.1 psig I

.Pressur,.-High SR 3.3.2.5 SR 3.32.8 SR 3.32.9

d. Prosaufzar 4 83 5 D SR 3.321 ?k pi 1B45 psag I Pressure - Low SR 3.325 LOW SR 3.32.8 SR 3.32.9

2. Contaimont Spray

a. Manual nifiation 1.2.3.4 I per trahi 8 SR 3.327 NA NA 2 trains

b. Autorabc 1.2..4 C SR 3322 NA NA AchnionL SR 3.32A and Aciaton SR 3.32.8 Relays

c. Corinert 1.23 4 E SR 3.321 :S30Opslg 2.S psig I Pmeam - Ho4 SR 339 High SR 3.3 SR 3.329

-: . Con~drurot Isolatn

a. Phase A Isc~abon (1) Mww 1.2 34 2 8 SR 3327 kikaton (2) Azionic 1.2 34 2 hkra C SR 322 NA NA Ackmation SR 32.4 Lo& and SR 3326 ARhabo (a) Abowth P-tl (Prasrizrsue) tWeock.

McGuire Unfts 1 and 2 3.3.2-10 Amendment Nos. 194/175

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMIINALI SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDmONS CHANNELS CONDmONS REQUIREMENTS VALUE SETPOIN1T

3. Containnt Isolation (3) Safety Refer to Function I (Safety Injection) for ntiatixon uncdo and reqrements.

b. Pha"e8Bolation (1) Manuai Initiation 1,2.3,4 1 per Imin. B SR 3.327 NA NA 2 trins (2) Autometic 1.23.4 2 trains C SR 3.3.2.2 NA NA Actuation SR 3.32.4 Logimad SR 32.6 Actuation Relays (3) cortakne 1.2.3 E SR 3Z2.1 3.0Opslg 2.gpsl I Pressure - SR 3.32.5 High Kih SR 3.3.2.8

4. Sm Lne Isolation

a. Manual Itaon (1) System 2 tans F SR 3.32.7 NA NA 1 .2 (b)A(b) 1 perlire a SR 3.32.7 NA NA 1.2M,3(b)

b. Aratic 2 train H SR 3.322 NA Acgaon Lo SR 332.4 eL Achation wid SR 3.32.

C. Co atkhiieit 1,2 4b), 3 (b) 4 E SR 3.32.1 ,3.0 " ps Psnw -High SR 3.325 pwg High SR 3.328 SR 3329

d. Starn Lkne (1) LOW 1 -(b). 3 (a)xb) 3 per stew D SR 3.321 ?k7 pa1g 775 psg I SR 332 SR 33.

SR 3.32.9 (a) Above VWu P-l I (PresazztzsPreew") te101 k (b Ee when aI MS1V* are closed end de-ecilvated.

McGuire Units I and 2 3.3.2-1 1 Amendment Nos. 194/175

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 6)

Engineered Safety Feature Actuation System Instrnentation APPLICABLE MODES OR OTHER NOMINALI SPECIFIED REQUIRED SURVEIL LLANCE ALLOWABLE TRIP FUNCTION CONDmONS CHANNELS CONDmONS REQUIRI EMENTS VALUE SETPOINTf

4. Steam Lh Isolation (continued)

(2) Ngative Rat - High 3 (b)(c) 3 per steam fine D SR 3.3.2.1 S 120'd) psi 100 (d) pr I SR 3.325 SR 3.32B SR 332.9

5. Tine Tip and Feedvaloor Isolation

a. Ahbmatic 1.2(0) 2 trainI SR 33.2.2 NA NA Actuation Logic SR 332.4 and Actuation SR 3.32B Relays

b. SOWaterLevel 1 2 (0) 3perSG J SR 332.1 £ 85.61% 83.9% l Hih High (P14) SR 33.2.2 SR 3.324 SR 3.32.5 SR 3326 SR 33.2.8 SR 3.329

c. Salty kjection Refer o Function I (Safey Iniection) for all Initiation hto and rquirnents.

d. T.,Low 1.2() 1 poroop SR 3.32.1 ?_5 5 1'F 553TF I SR 3.32-5 SR 3.32.8 coidoe wkm Rolar o Function 8.a (Rear Tp P4) for a Initiation fu and RacrTrip. P4 requreet.

. Doghoso Water 12(0) 2 per tan LM SR 3..1 L.13 inches 12bkxas I Level-h High Per SR 337 Dm 6 Ailiary Feedata

a. Auaad 12.3 2 taku H SR 332 NA NA Aftuaficn Logic SR 324 mid Actuation SR 3.3,!6 Relays

b. SG WatrLevel - 1.2.3 4 per SG 0 SR 332.1 k 16% 15.7%

Low Low SR 335 SR 33.Z8 SR 3.39 (ti) Emt vuen ad MSIVa we closed wid do~alvalad.

(C) Trip kxxton aubmstialy biodcad abiove P-1Il (Pressurizer Presur) Intorocit end may be blaciddblo P.1 1 vwhsn Safety hledtn Stboo Lhw Prewelmw Is not boced.

(d) Time wwta- utied hi ft rabatg wr*ar Is2 50 scords.

(a) Eeciuen all MFIV, MFCV, and associated bypass vahvs are od d decvad or Isolated by a closed manual vat".

McGuire Units 1 and 2 3.3.2-12 Amendment Nos. 194/175

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT

6. Auxiliary Feedwater (continued)

c. Safety Injection Refer to Function 1 (Safety Injection) for all nitiation functions and requirements.

d. Station Blackout (1) Loss of 1.2.3 3 per bus D SR 3.3.2.7 > 3122 V (Unit 3174 V voltage SR 3.3.2.9 1) 3108V (Unit 1)

(Unit 2) with 3157 V 8.5 0.5 sec (Unit 2) +/-

time delay 45 V with 8.5t +/-0.5 sec time delay (2) Degraded 1,2,3 3 per bus D SR 3.3.2.7 > 3661 V (Unit 3678.5 V Voltage SR 3.3.2.9 1) 3685.5 V (Unit 1)

(Unit 2) 3703 V with 11 sec (Unit 2) with SI and with < 11

< 600 sec sec with SI without Si and < 600 time delay sec without SI time delay

e. Trip of all Main 1 per MFW K SR 3.3.2.7 NA NA Feedwater pump SR 3.3.2.9 Pumps

f. Auxiliary 1,2,3 2 per MDP N,O SR 3.3.2.7 3 psig 3.5 psig Feedwater Pump 4 per TDP SR 3.3.2.8 Suction Transfer SR 3.3.2.9 on Suction Pressure - Low

7. Automatic Switchover to Containment Sump

a. Refueling Water 1,2,3 3 P. S SR 3.3.2.1 > 175.85 180 inches Storage Tank SR 3.3.2.3 inches (RWST) Level- SR 3.3.2.8 Low SR 3.3.2.9 Coincident with Refer to Function 1 (Safety Injection) for all nitiation functions and requirements.

Safety Injection (continued)

(a) Above the P-i1 (Pressurizer Pressure) Interlock.

McGuire Units and 2 3.3.2-1 3 Amendment Nos. 198/179

ESFAS Instrumentation 3.3.2 Tabl 3.32-1 (page 5 of 6)

Engineered Safety Feature Actuation System Istrumentaton APPUCABLE MODES OR OTHER NOMI1NAL SPECIFIED REOUIRED SURVEIL LANCE ALLOWABLE TRIP FUNClION CONDITIONS CHANNELS CONDONS REOUIRE IMENTS VALUE SETPOINT

8. ESFAS Irterlods

a. Reactor Trip, P-4 1.20 t per tra F SR 3327 NA NA 2 trains

b. Pressuri I.2"3 3 a SR 3325 5 1965 ll l9S5)Sg I Pressure, P-1I SR 332.8

c. T_ -Low Low, 1.2.3 1pop O SR 332.5 ?-551'F 53F I P-12 SR 332.8

9. Containment. t,2,3.4 4 pertrain. R SR 3.3+/-1 Reher to Note Refer to Pressure Controt 2 trains SR 332.3 I on Page Note I on system SR 33Z8 3Z2-15 page 32-15 McGuire Units 1 and 2 3.3.2-1i4 Amendment Nos. 194/175

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (Page 6 of 6)

Engineered Safety Features Actuation System Instrumentation NOTE 1: The Trip Setpoint for the Containment Pressure Control System start permissive/termination (SPIT) shall be > 0.3 psig and < 0.4 psig. The allowable value for the SPIT shall be > 0.25 psig and < 0.45 psig.

McGuire Units and 2 3.3.2-1 5 Amendment Nos. 184/166

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

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

___________------------ ---- NI tS~~~~~~~~~~--- - ----- -_-________

1. LCO 3.0.4 is not applicable.

2. Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more referenced in Table 3.3.3-1 required channels for the channel.

inoperable.

B. One or more Functions B.1 Restore required channel 30 days with one required to OPERABLE status.

channel inoperable.

C. Required Action and C.1 Initiate action in Immediately associated Completion accordance with Time of Condition B not Specification 5.6.7 met.

D. One or more Functions D.1 Restore required channel 7 days with one required to OPERABLE status.

channel inoperable.

(continued)

McGuire Units 1 and 2 3.3.3-1 Amendment Nos. 184/166

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more Functions E.1 Restore one channel to 7 days with two required OPERABLE status.

channels inoperable.

F. Two hydrogen monitor F.1 Restore one hydrogen 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channels inoperable. monitor channel to OPERABLE status.

G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition D, E AND or F not met.

G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months H. Required Action and H.1 Initiate action in Immediately associated Completion accordance with of Condition D not met. Specification 5.6.7.

McGuire Units 1 and 2 3.3.3-2 Amendment Nos. 184/166

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS SR 3.3.3.1 and SR 3.3.3.3 apply to each PAM instrumentation Function in Table 3.3.3-1.

__~~~~~ -- - -- -- -- -- - -- - --- - -- - -- -_ ____

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 --- ---------- NOTE--------

This SR is only applicable to Hydrogen Monitors.

Perform CHANNEL CALIBRATION. 92 days SR 3.3.3.3 ---- N OT--NT----------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months McGuire Units 1 and 2 3.3.3-3 Amendment Nos. 184/166

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1)

Post Accident Monitoring Instrumentation FUNCTION REQUIRED CHANNELS CONDITIONS

1. Neutron Flux (Wide Range) 2 B,CEG

2. Reactor Coolant System (RCS) Hot Leg Temperature 2 B.CE.G

3. RCS Cold Leg Temperature 2 B,C,EG

4. RCS Pressure (Wide Range) 2 BC,E,G

5. Reactor Vessel Water Level (Dynamic Head Range) 2 BC,EG

6. Reactor Vessel Water Level (Lower Range) 2 B.C.E,G

7. Containment Sump Water Level (Wide Range) 2 BCEG

8. Containment Pressure (Wide Range) 2 BCE,G

9. Containment Atmosphere Radiation (High Range) 1 D,H

10. Hydrogen Monitors 2 BC,F,G

11. Pressurizer Level 2 BC,EG

12. Steam Generator Water Level (Narrow Range) 2 per steam generator B,C,EG

13. Core Exit Temperature - Quadrant 1 2 (a)

BC.EG

14. Core Exit Temperature - Quadrant 2 2 (a) BC.E.G

15. Core Exit Temperature - Quadrant 3 2 (a) BC,E.G

16. Core Exit Temperature - Quadrant 4 2 (a)

B,C,EG

17. Auxiliary Feedwater Flow 2 per steam generator B.C,E,G

18. RCS Subcooling Margin Monitor 2 B.C,E,G

19. Steam Line Pressure 2 per steam generator B.C,EG

20. Refueling Water Storage Tank Level 2 B.C,EG

21. DG Heat Exchanger NSWS Flow(b) 1 per DG D,G

22. Containment Spray Heat Exchanger NSWS Flow(b) 1 per train D,G (a) A channel consists of two core exit thermocouples (CETs).

(b) Not applicable If the associated outlet valve is set to its flow balance position with power removed or if the associated outlet valve's flow balance position is fully open.

McGuire Units and 2 3.3.3-4 Amendment Nos. 184/166

Remote Shutdown System 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown System LCO 3.3.4 The Remote Shutdown System Functions in Table 3.3.4-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-NOTI=S------

1. LCO 3.0.4 is not applicable.

2. Separate Condition entry is allowed for each Function.

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

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.3.4-1 Amendment Nos. 184/166

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.4.2 Verify each required control circuit and transfer switch is 18 months capable of performing the intended function.

SR 3.3.4.3 Perform CHANNEL CALIBRATION for each required 18 months instrumentation channel.

McGuire Units 1 and 2 3.3.4-2 Amendment Nos. 184/166

Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of 1)

Remote Shutdown System Instrumentation and Controls FUNCTION/INSTRUMENT REOUIRED OR CONTROL PARAMETER NUMBER OF FUNCTIONS

1. Reactivity Control

a. Reactor Trip Breaker Position 1 per trip breaker

2. Reactor Coolant System (RCS) Pressure Control

a. Pressurizer Pressure 1

3. Decay Heat Removal via Steam Generators (SGs)

a. RCS Hot Leg Temperature - Loop D 1

b. SG Pressure 1 perSG

c. SG Level 1 perSG or AFW Flow

4. RCS Inventory Control

a. Pressurizer Level 1 McGuire Units 1 and 2 3.3.4-3 Amendment Nos. 184/166

LOP DG Start Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation LCO 3.3.5 Three channels per bus of the loss of voltage Function and three channels per bus of the degraded voltage Function 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 9I I.%Trr I------------ ------ ---- ----- NUj~k I1 ---- ----------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months with one channel per bus inoperable.

B. One or more Functions B.1 Restore all but one channel 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with two or more to OPERABLE status.

channels per bus inoperable.

C. Required Action and C.1 Enter applicable Immediately associated Completion Condition(s) and Required Time not met. Action(s) for the associated DG made inoperable by LOP DG start instrumentation.

McGuire Units 1 and 2 3.3.5-1 Amendment Nos. 184/166

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform TADOT. 31 days SR 3.3.5.2 NOTE A NOMINAL TRIP SETPOINT associated with this SR shall be set within the channel's calibration tolerance band.

Perform CHANNEL CAUBRATION with NOMINAL TRIP 18 months I

SETPOINT and Allowable Value as follows:

a. Loss of voltage Allowable Value > 3122 V (Unit 1)

> 3108 V (Unit 2) with a time delay of 8.5

0.5 second.

Loss of voltage NOMINAL TRIP SETPOINT 3174 V (Unit 1) 3157 V (Unit 2) t 45 V with a time delay of 8.5

0.5 second. I

b. Degraded voltage Allowable Value > 3661 V (Unit

1) > 3685.5 V (Unit 2) with a time delay of 11 seconds with Si and < 600 seconds without SI.

Degraded voltage NOMINAL TRIP SETPOINT 3678.5 V (Unit 1) 3703 V (Unit 2) with a time delay of < 11 seconds with SI and < 600 seconds without Si.

McGuire'Units 1 and 2 3.3.5-2 Amendment Nos. 194/175

Containment Purge and Exhaust Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION 3.3.6 Containment Purge and Exhaust Isolation Instrumentation LCO 3.3.6 The Containment Purge and Exhaust Isolation instrumentation for each Function in Table 3.3.6-1 shall be OPERABLE.

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

ACTIONS KIPNIrr

a---------------I-l I Separate Condition entry is allowed for each Function.

_~~~~~~~~-

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter applicable Conditions Immediately with one or more manual and Required Actions of or automatic actuation LCO 3.6.3, Containment trains inoperable. Isolation Valves,' for containment purge and exhaust isolation valves made inoperable by isolation instrumentation.

McGuire Units 1 and 2 3.3.6-1 Amendment Nos. 184/166

Containment Purge and Exhaust Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS I. I^lrf-I - --- --- --------- _________

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge and Exhaust Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.6.2 Perform MASTER RELAY TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.6.3 Perform SLAVE RELAY TEST. 92 days SR 3.3.6.4 ------------

Verification of setpoint is not required.

Perform TADOT. 18 months McGuire Units 1 and 2 3.3.6-2 Amendment Nos. 184/166

Containment Purge and Exhaust Isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 o 1)

Containment Purge and E idtust Isolation Instrumentation SURVEILLANCE NOMINALT RIP FUNCTION REQUIRED CHANNELS REQUIREMENTS SETPOIN T

1. ManuaJ Initiation 2 SR 3.3.6.4 NA

2. Aukmtic Actuation Logic and 2 trains SR 3.3.6.1 NA Acbatbon Relays SR 3.3.6.2 SR 33.63

3. Safety kJoction Refer to LCO 332. ESFAS Inshmntbon. Function 1 for all hItiation functions and requirement.

McGuire Units I and 2 3.3.6-3 Anendment Nos. 194/175

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified in Table 3.4.1-1.

APPLICABILITY: MODE 1.

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp > 5% RTP per minute; or

b. THERMAL POWER step > 10% RTP. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer pressure or A.1 Restore DNB parameter(s) 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months RCS average to within limit.

temperature DNB parameters not within limits.

B. RCS total flow rate B.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

< 390,000 gpm but POWER to < 98% RTP.

> 386,100 gpm.

AND B.2 Reduce the Power Range 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Neutron Flux - High Trip Setpoint below the nominal setpoint by 2% RTP.

(continued)

McGuire Units 1 and 2 3.4.1-1 Amendment tlos. 191 (Unit 1) 172 (Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 ACTIONS (continued) _ _.

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS total flow rate C.1 Restore RCS total flow rate 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

< 386,100 gpm. to > 386,100 gpm. I OR C.2.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to < 50% RTP.

AND C.2.2 Reduce the Power Range 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Neutron Flux - High Trip Setpoint to < 55% RTP.

AND I C.2.3 Restore RCS total flow rate 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to > 386,100 gpm.

D. Required Action and D.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.4.1-2 Amendment Nos. 191 (Unit 1) 172 (Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.2 Verify RCS average temperature is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.3 Verify RCS total flow rate is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.4 Perform CHANNEL CALIBRATION for each RCS total 18 months flow indicator.

McGuire Units 1 and 2 3.4.1 -3 Amendment Nos. 184/166

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 Table 3.4.1-1 (page 1 of 1)

RCS DNB Parameters PARAMETER INDICATION No. OPERABLE LIMITS CHANNELS

1. Indicated RCS Average meter 4 < 587.2 F Temperature meter 3 <586.9 0F computer 4 <587.7 F computer 3 1 <587.5 F

2. Indicated Pressurizer meter 4 > 2219.8 psig Pressure meter 3 > 2222.1 psig computer 4 > 2215.8 psig computer 3 > 2217.5 psig

3. RCS Total Flow Rate > 390,000 gpm.

McGuire Units 1 and 2 3.4.1-4 Amendment Nos. 191 (Unit 1) 172 (Unit 2)

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (Tavg) shall be > 551'F.

APPLICABILITY: MODE 1, MODE 2 with ke > 1.0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Tavg in one or more RCS A.1 Be in MODE 2 with Kff 30 minutes loops not within limit. <1.0.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop > 551 IF. -- NOTE--

Only required if Tavg - Tf deviation alarm not reset and any RCS loop Tayg < 561'F 30 minutes McGuire Units 1 and 2 3.4.2-1 Amendment Nos. 184/166

RCS P/T Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (P/T) Limits LCO 3.4.3 RCS pressure and RCS temperature shall be limited during RCS heatup and cooldown, criticality, and inservice leak and hydrostatic testing in accordance with:

a. A maximum heatup rate as specified in Figure 3.4.3-1, Figure 3.4.3-2, Figure 3.4.3-3, or Figure 3.4.3-4; 1

b. A maximum cooldown rate as specified in Figure 3.4.3-5 or Figure 3.4.3-6; and I

c. A maximum temperature change of < 1 F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period during inservice leak and hydrostatic testing operations above the heatup and cooldown limit curves.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------------ NOTE---------- A.1 Restore parameter(s) to 30 minutes Required Action A.2 within limits.

shall be completed whenever this Condition AND is entered.

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acceptable for continued Requirements of LCO operation.

not met in MODE 1, 2, 3, or 4.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5 with RCS 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure < 500 psig.

(continued)

McGuire Units 1 and 2 3.4.3-1 Amendment Nos. 214 & 195

RCS P/T Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. --- -- NOTE------ C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed limits.

whenever this Condition is entered. AND C.2 Determine RCS is Prior to entering Requirements of LCO acceptable for continued MODE 4 not met any time in other operation.

than MODE 1, 2, 3, or 4.

SURVEILLANCE REQUIREMENTS 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 30 minutes and cooldown rates are within limits.

McGuire Units 1 and 2 3.4.3-2 Amendment Nos. 184/166

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL: LOWER SHELL LONGITUDINAL WELD LIMITING ART VALUES AT 34 EFPY: I14T, 202°F 3t4T, 146°F 2500 2250 2000 1750 Li L.

Li 1500 fr 1250

._z 1000 0

I-L.

_0 750 gI c

500 250 0

0 50 100 150 200 250 300 350 400 450 500 550 Reactor Beltline Rezion Fluid Temverature (Dee. F)

Figure 3.43-1 INMcGuire Unit I Reactor Coolant System Heatup Limitations (Heatup Rate of 60°F/hr) Applicable for the First 34 EFPY (WNithout M\Jargins for Instrumentation Errors) Using 1996 App.G Miethodology & ASIE Code Case N-641 McGuire Units 1 and 2 3.4.3-3 Amendment Nos. 214 & 195

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL- LOWER SHELL LONGITUDINAL WELD LIMITING ART VALUES AT 34 EFPY: 1/4T, 2020 F 3/4T, 146cF 2500 l0perlim Verslon:5.1 Run:22278 2250 - -Leek Test Limit I. . . .L.. - ......

I 2000 Acceptable Operation Unacceptable I Operaton I' 1750 Critical Limit M1500 Heatup Rate jA OD Deg. F/Hr .-

td c 1250 lI Heatup Raiel 1°° Deg Fr c 1000 U,

c 750 4.... _.

I-I

.S 500 c

W.

I

1I 250 -----j B - itup -. _.... ICriticality Limit based on Temp. Inservice hydrostatic test i temperature (262 F) for the

. service period up to 34 EFPY 0 .

. . . . I ._ . . . . . ..

0 50 100 150 200 250 300 350 400 450 500 550 Reactor Beltine Region Fluid Temperature (Deg. F)

Figure 3.4.3-2 MlcGuire Unit I Reactor Coolant System Heatup Limitations (Heatup Rates of 80 &

100°F/hr) Applicable for the First 34 EFPY (Without M5argins for Instrumentation Errors) Using 1996 App.G Methodology & ASIE Code Case N-641 McGuire Units 1 and 2 3.4.3-4 Amendment Nos. 214 & 195

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL: LOWER SHELL FORGING 04 LIMITING ART VALUES AT 34 EFPY: 114T. 123 0F 314T, 91 0F 2500 2250 2000 1750 C-,

v 1500 C

1250 P

c 1000 750 e

V 500 250 0

0 50 100 150 200 250 300 350 400 450 500 550 Reactor Beltline Region Fluid Temperature (Deg. F)

Figure 3.43-3 ]MIcGuire Unit 2 Reactor Coolant System Heatup Limitations (Heatup Rate of 60'F/hr) Applicable for the First 34 EFPY (Without Margins for Instrumentation Errors) Using 1996 App.G Mfethodology & ASMIE Code Case N-641 McGuire Units 1 and 2 3.4.3-5 Amendment Nos. 214 & 195

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL: LOWER SHELL FORGING 04 LIMITING ART VALUES AT 34 EFPY: 1/4T, 123 0 F 3/4T, 91 0F 2500 2250 2000 1750 Us.

1500 E

0 1250 e

I 1000 750

~1 Cw C

500 250 0

0 50 100 150 200 250 300 350 400 450 500 550 Reactor Beltline Region Fluid Temperature (Deg. F)

Figure 3.4.3-4 MlcGuire Unit 2 Reactor Coolant System Heatup Limitations (Heatup Rates of 80 &

100 0F/ir) Applicable for the First 34 EFPY (Without Margins for Instrumentation Errors) Using 1996 App.G Methodology & ASMIE Code Case N-641 McGuire Units 1 and 2 3.4.3-6 Amendment Nos. 214 & 195

RCS P/T Limits 3.4.3 1ATERIAL PROPERTY BASIS LIMITING MATERIAL: LOWER SHELL LONGITUDINAL WELD LIMITING ART VALUES AT 34 EFPY: 1/4T, 202°F 314T, 146°F 2500 1.

1Operhim Version:5.1 Run:22278 2250 .~ ~~~~ . ', .

lUnaccepta blel ---

2000 - Operation -

1750 - lAcceptable i v

I Operation L.

~~e~~~b~~~e~

c

. 1500 -

Q C.

- 1250 -

Cooldown /

tt Rates F/ r 1000 - stady-state _-

.20 c .40 u I-so I L. 750-C Soo-

/ 1: i _.__ _ _ _._* . _ . . _ .~~~~~

i I

250 -- Boltup emp.. -

r I S i L I 0 .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~

I - I T ..... T..ll T

0 50 100 150 200 250 300 350. 400 450 500 550 Reactor Beltline Region nluid Temperature (Deg. F)

Figure 3.4.3-5 MIcGuire Unit I Reactor Coolant Sy stem Cooldown Limitations (Cooldown Rates up to 1000 F/hr) Applicable for the First 34 EFPY (Without 1argins for Instrumentation Errors) Using 1996 App.G MIethodology & ASIE Code Case N-641 McGuire Units 1 and 2 3.4.3-7 Amendment Nos. 214 & 195

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL: LOWER SHELL FORGING 04 LIMITING ART VALUES AT 34 EPPY: 1/4T, 1230 F 3/4T, 91 0F 2500 loperlim Version:5 .1 Run:30646 I i 2250-2000 1750 - -. ~~~~Acceptable -

Operton L.

75 1500 C-1250 -

L.

1000 -

C

'I 750 -

t I

500 -

I i 250 -

I I I

, ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~

I II I I I I 0

0 50 100 150 200 250 300 350 400 450 500 550 Reactor Beitline Region Fluid Temperature (Deg. F)

Figure 3.4.3-6 McGuire Unit 2 Reactor Coolant System Cooldown Limitations (Cooldown Rates up to 1O 0 F/hr) Applicable for the First 34 EFPY (Without Margins for Instrumentation Errors) Using 1996 App.G Methodology & ASME Code Case N-641 McGuire Units 1 and 2 3.4.3-8 3438A Amendment e d e t Nos.

N s 2141 195 9

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops-MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.4.4-1 Amendment Nos. 184/166

RCS Loops - MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops-MODE3 LCO 3.4.5 Three RCS loops shall be OPERABLE, and either:

a. Three RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal; or

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

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

All reactor coolant pumps may be de-energized for < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1 and maintain Keff < 0.99; and

b. Core outlet temperature is maintained at least 1 F below saturation temperature.

APPLICABILITY: MODE 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Restore required RCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months RCS loop(s) inoperable. loop(s) to OPERABLE status.

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

(continued)

McGuire Units 1 and 2 3.4.5-1 Amendment Nos. 216 & 197

RCS Loops - MODE 3 3.4.5 ACTIONS (continued),

CONDITION REQUIRED ACTION COMPLETION TIME C. One or two required C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RCS loop(s) not in loop(s) to operation.

operation and Rod Control System capable OR of rod withdrawal.

C.2 De-energize all control rod 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months drive mechanisms (CRDMs).

D. Three required RCS D.1 De-energize all CRDMs. Immediately loops inoperable.

AND OR D.2 Suspend operations that Immediately No RCS loop in would cause introduction of operation. coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

McGuire Units 1 and 2 3.4.5-2 AmendmentNos.216 & 197

RCS Loops - MODE 3 3.4.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.5.2 Verify steam generator secondary side water levels are 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

> 12% narrow range for required RCS loops.

SR 3.4.5.3 Verify correct breaker alignment and indicated power are 7 days available to the required pumps that are not in operation.

McGuire Units 1 and 2 3.4.5-3 Amendment Nos. 184/166

RCS Loops - MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops-MODE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

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

1. All reactor coolant pumps (RCPs) and RHR pumps may be de-energized for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1 and maintain Keff <

0.99; and

b. Core outlet temperature is maintained at least 1 F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature < 3000 F unless:

a. Secondary side water temperature of each steam generator (SG) is < 500 F above each of the RCS cold leg temperatures, or

b. Pressurizer water level is < 92% (1600 ft3).

APPLICABILITY: MODE 4.

ACTIONS .

CONDITION REQUIRED ACTION COMPLETION TIME A. One RCS loop A.1 Initiate action to restore a Immediately OPERABLE. second loop to OPERABLE status.

AND Two RHR loops inoperable.

(continued)

McGuire Units 1 and 2 3.4.6-1 Amendment Nos. 216 & 197 -

RCS Loops - MODE 4 3.4.6 ACTIONS (continued) _

CONDITION REQUIRED ACTION COMPLETION TIME B. One RHR loop B.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE.

AND ALL RCS loops inoperable.

C. Both required RCS or C.1 Suspend operations that Immediately RHR loops inoperable. would cause introduction of coolant into the RCS with OR boron concentration less than required to meet the No RCS or RHR loop in SDM of LCO 3.1.1 and operation. maintain Keff < 0.99.

AND C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop Is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side water levels are > 12% narrow 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months range for required RCS loops.

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

McGuire Units 1 and 2 3.4.6-2 Amendment Nos.216 & 197

RCS Loops - MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops-MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a. One additional RHR loop shall be OPERABLE; or

b. The secondary side water level of at least two steam generators (SGs) shall be > 12% narrow range.

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

1. The RHR pump of the loop in operation may be de-energized for

< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 1 F below saturation temperature.

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

3. No reactor coolant pump shall be started with one or more RCS cold leg temperatures < 300'F unless:

a. Secondary side water temperature of each SG is < 501F above each of the RCS cold leg temperatures, or

b. Pressurizer water level is < 92% (1600 ft3).

4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

APPLICABILITY: MODE S with RCS loops filled.

McGuire Units and 2 3.4.7-1 Amendment Nos. 216 & 197

RCS Loops - MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore a Immediately inoperable. second RHR loop to OPERABLE status.

AND OR Required SGs secondary side water A.2 Initiate action to restore Immediately levels not within limits. required SG secondary side water levels to within limits.

B. Required RHR loops B.1 Suspend operations that Immediately inoperable. would cause introduction of coolant into the RCS with OR boron concentration less than required to meet SDM No RHR loop in of LCO 3.1.1.

operation.

AND Immediately B.2 Initiate action to restore one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.2 Verify SG secondary side water level is > 12% narrow 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months range in required SGs.

McGuire Units 1 and 2 3.4.7-2 Amendment Nos. 216 & 197

RCS Loops - MODE 5, Loops Filled 3.4.7 SR 3.4.7.3 Verify correct breaker alignment and indicated power are 7 days available to the required RHR pump that is not in operation.

McGuire Units 1 and 2 3.4.7-3 AmendmentNos.216 & 197

RCS Loops - MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops-MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation.

--- - - ------ - - - - ----------- N OTES

1. All RHR pumps may be de-energized for < 15 minutes when switching from one loop to another provided:

a. The core outlet temperature is maintained at least 10OF below saturation temperature.

b. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

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

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

APPLICABILITY: MODE 5 with RCS loops not filled.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore Immediately inoperable. RHR loop to OPERABLE status.

(continued)

McGuire Units 1 and 2 3.4.8-1 Amendment Nos. 216 & 197

RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend operations that Immediately inoperable. would cause introduction of coolant into the RCS with OR boron concentration less than required to meet SDM No RHR loop in of LCO 3.1.1.

operation.

AND B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated power are 7 days available to the required RHR pump that is not in operation.

McGuire Units and 2 3.4.8-2 Amendment Nos. 216 & 197

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a. Pressurizer water level < 92% (1600 ft3); and

b. Two groups of pressurizer heaters OPERABLE with the capacity of each group > 150 kW.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water level A.1 Be in MODE 3 with reactor 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not within limit. trip breakers open.

AND A.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B. One required group of B.1 Restore required group of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressurizer heaters pressurizer heaters to inoperable. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not AND met.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.4.9-1 Amendment Nos. 184/166

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is < 92% (1600 ft3). 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.9.2 Verify capacity of each required group of pressurizer 92 days heaters is > 150 kW.

McGuire Units 1 and 2 3.4.9-2 Amendment Nos. 184/166

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.1 0 Three pressurizer safety valves shall be OPERABLE with lift settings

> 2435 psig and < 2559 psig.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures > 300'F.

--- - ------ _- ------ N t -_--__________________

The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months 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 A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RCS cold leg temperatures Two or more pressurizer < 300 0F.

safety valves inoperable.

McGuire Units 1 and 2 3.4.1 0-1 Amendment Nos. 184/166

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in In accordance with accordance with the Inservice Testing Program. the Inservice Following testing, lift settings shall be > 2460 psig and Testing Program

< 2510 psig.

McGuire Units 1 and 2 3.4.10-2 Amendment Nos. 184/166

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

1. Separate Condition entry is allowed for each PORV.

2. LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain power 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and capable to associated block valve.

of being manually cycled.

B. One or two PORVs -------- NOTE--

inoperable and not Required Actions B.1 and B.2 are capable of being not applicable to a PORV made manually cycled. inoperable by Required Action C.2.

B.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months valves.

AND B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

AND (continued)

McGuire Units 1 and 2 3.4.1 1-1 Amendment Nos. 184/166

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3 Restore one PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status if two PORVs are inoperable.

C. One block valve C.1 Place associated PORV 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. switch in closed position and verify PORV closed.

AND C.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated PORV.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, AND or C not met.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Three PORVs E.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and not valves.

capable of being manually cycled. AND E.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

AND E.3 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.4 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

McGuire Units and 2 3.4.11-2 Amendment Nos. 184/166

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two block valves F.1 Place associated PORV 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. switches in closed position and verify PORVs closed.

AND F.2 Restore one block valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

G. Three block valves G.1 Place associated PORV 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. switches in closed position and verify PORVs closed.

AND G.2 Restore one block valve to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

H. Required Action and H.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F or G AND not met.

H.2 Be in MODE 4. .12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.4.1 1-3 Amendment Nos. 184/166

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 ------- -------- NOTE-------- --------

Not required to be met with block valve closed in accordance with the Required Action of Condition A, B, or E.

Perform a complete cycle of each block valve. 92 days SR 3.4.11.2 --------------- NOTE---- -------

Required to be performed in MODE 3 or MODE 4 when the temperature of all RCS cold legs is > 300F and the block valve closed.

Perform a complete cycle of each PORV. 18 months SR 3.4.11.3 Verify the nitrogen supply for each PORV is OPERABLE 18 months by:

a. Manually transferring motive power from the air supply to the nitrogen supply,

b. Isolating and venting the air supply, and

c. Operating the PORV through one complete cycle.

McGuire Units 1 and 2 3.4.1 1-4 Amendment Nos. 184/166

LTOP System 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12 An LTOP System shall be OPERABLE with a maximum of one centrifugal charging pump or one safety injection pump capable of injecting into the RCS and the accumulators isolated and either a or b below:

a. Two power operated relief valves (PORVs) with lift setting < 385 psig or

b. The RCS depressurized and an RCS vent of > 2.75 square inches.

-- _-- ---------- OTE---- ----- -

A PORV secured in the open position may be used to meet the RCS vent requirement provided that its associated block valve is open and power removed.

APPLICABILITY: MODE 4 when any RCS cold leg temperature is < 3000 F, MODE 5, MODE 6 when the reactor vessel head is on.

ka C

NUt I t - -- - __________

Accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in Specification 3.4.3.

McGuire Units 1 and 2 3.4.1 2-1 Amendment Nos. 184/166

LTOP System 3.4.12 ACTIONS

_-_------------- --------------------- -N OTE-LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Two centrifugal charging A.1 ---- NOTE-- ----- ----

pumps capable of Two centrifugal charging injecting into the RCS. pumps may be capable of injecting into the RCS OR during pump swap operation for 15 minutes.

One centrifugal charging pump and one safety Initiate action to verify a Immediately injection pump capable maximum of one centrifugal of injecting into the RCS. charging pump or one safety injection pump is OR capable of injecting into the RCS.

Two safety injection pumps capable of OR injecting into the RCS.

A.2.1 Verify RHR suction relief Immediately valve is OPERABLE and the suction isolation valves are open.

AND A.2.2.1 Verify RCS cold leg Immediately temperature > 1740 F (Unit

1) or > 890 F (Unit 2). I OR A.2.2.2Verify RCS cold leg Immediately temperature > 740 F and cooldown rate < 20'F/ hr (Unit 1), or > 740 F and cooldown rate < 6 0°F/hr (Unit 2).

OR (continued)

McGuire Units 1 and 2 3.4.12-2 Amendment Nos. 214 & 195

LTOP System 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Verify two PORVs secured Immediately open and associated block valves open and power removed.

OR A.4 Depressurize RCS and Immediately establish RCS vent of > 4.5 square inches.

OR A.5.1 Depressurize RCS and Immediately establish RCS vent of

> 2.75 square inches.

AND A.5.2 Verify two PORVs are Immediately OPERABLE.

B. An accumulator not B.1 Isolate affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolated when the accumulator.

accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in Specification 3.4.3.

C. Required Action and C.1 Increase RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion temperature to > 3000 F.

Time of Condition B not met. OR C.2 Depressurize affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed by Specification 3.4.3.

D. One PORV inoperable in D.1 Restore PORV to 7 days MODE 4. OPERABLE status.

(continued)

McGuire Units 1 and 2 3.4.1 2-3 Amendment Nos. 214 & 195

LTOP System 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One PORV inoperable in E.1 Suspend all operations Immediately MODE 5 or 6. which could lead to a water solid pressurizer.

AND E.2 Restore PORV to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

F. Required Action and F.1. Verify RCS cold leg 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion temperature > 1740 F (Unit Time of Condition E not 1) or > 891F (Unit 2).

met.

AND F.2 Verify RHR suction relief valve is OPERABLE and 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the suction isolation valves are open.

G. Two PORVs inoperable. G.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months establish RCS vent of OR > 2.75 square inches.

Required Action and associated Completion Time of Condition C, D, E, or F not met.

OR LTOP System inoperable for any reason other than Condition A, B, C, D, E, or F.

McGuire Units 1 and 2 3.4.12-4 Amendment Nos. 214 & 195

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one centrifugal charging pump or 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months one safety injection pump is capable of injecting into the RCS.

SR 3.4.12.2 Verify each accumulator is isolated. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.12.3 Verify RHR suction isolation valves are open when the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RHR suction relief valve is used for overpressure protection.

SR 3.4.12.4 -------- -------- NOTE -----------------

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

Verify RCS vent > 2.75 square inches open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked open vent valve(s)

AND 31 days for locked open vent valve(s)

SR 3.4.12.5 Verify PORV block valve is open for each required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months PORV.

(continued)

McGuire Units 1 and 2 3.4.1 2-5 Amendment Nos. 184/166

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.6 -------------- NOTE-------------------

Not required to be met until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to < 300 0F.

Perform a COT on each required PORV, excluding 31 days actuation.

SR 3.4.12.7 Perform CHANNEL CALIBRATION for each required 18 months PORV actuation channel.

McGuire Units 1 and 2 3.4.12-6 Amendment Nos. 184/166

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE;

d. 389 gallons per day total primary to secondary LEAKAGE through all steam generators (SGs); and

e. 135 gallons per day primary to secondary LEAKAGE through any one SG.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS LEAKAGE not A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within limits for reasons within limits.

other than pressure boundary LEAKAGE.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

McGuire Units 1 and 2 3.4.1 3-1 Amendment Nos. 184/166

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 1.

SR 3.4.13.1 IVNt e-------- _ -----NOTE------

Not required to be performed in MODE 3 or 4 until Only required to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation. be performed during steady state operation Verify RCS Operational LEAKAGE is within limits by 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months performance of RCS water inventory balance.

SR 3.4.13.2 Verify steam generator tube integrity is in accordance In accordance with with the Steam Generator Tube Surveillance Program. the Steam Generator Tube Surveillance Program McGuire Units 1 and 2 3.4.13-2 Amendment Nos. 184/166

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) flow path when in, or during the transition to or from, the RHR mode of operation.

ACTIONS ti _--- ___________

1. Separate Condition entry is allowed for each flow path.

2. 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 -------- NT-NOTE------- ----

with leakage from one or Each valve used to satisfy more RCS PIVs not Required Action A.1 must have within limit. been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system.

(continued)

McGuire Units 1 and 2 3.4.1 4-1 Amendment Nos. 184/166

RCS PIV Leakage 3.4.14 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.1 Isolate the high pressure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND A.2 Restore RCS PIV to within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A not AND met.

B.2 Be in MODE 5. *36hours C. RHR System interlock C.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months function inoperable. penetration by use of one closed manual or deactivated automatic valve.

McGuire Units 1 and 2 3.4.14-2 Amendment Nos. 184/166

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

.1.

SR 3.4.14.1 --------------------- NOTE-----------------------

1. Not required to be performed in MODES 3 and 4.

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

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to < 0.5 In accordance with gpm per nominal inch of valve size up to a maximum of 5 the Inservice gpm at an RCS pressure > 2215 psig and < 2255 psig. Testing Program, and 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 AND Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve (continued)

McGuire Units 1 and 2 3.4.1 4-3 Amendment Nos. 184/166

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.14.2 Verify RHR system interlock prevents the valves from 18 months being opened with a simulated or actual RCS pressure signal > 425 psig.

McGuire Units 1 and 2 3.4.1 4-4 Amendment Nos. 184/166

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. The containment floor and equipment sump level monitoring system;

b. One containment atmosphere gaseous radioactivity monitor; and

c. Either the containment ventilation condensate drain tank level monitor or the containment atmosphere particulate radioactivity monitor.

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

ACTIONS LCO-3.0.4-is-notapp------licable. I- - -_--_-

LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Containment floor and A.1 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months equipment sump level monitoring system AND inoperable.

A.2 Restore containment floor 30 days and equipment sump level monitoring system to OPERABLE status.

(continued)

McGuire Units 1 and 2 3.4.1 5-1 Amendment Nos. 184/166

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Containment B.1 Analyze grab samples of Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months atmosphere gaseous the containment radioactivity monitor atmosphere.

inoperable.

OR B.2 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. Containment C.1 Restore containment 30 days atmosphere particulate atmosphere particulate radioactivity monitor radioactivity monitor to inoperable. OPERABLE status.

AND OR Containment ventilation C.2 Restore containment 30 days condensate drain tank ventilation condensate level monitor inoperable. drain tank level monitor to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. All required monitors E.1 Enter LCO 3.0.3. Immediately inoperable.

McGuire Units 1 and 2 3.4.1 5-2 Amendment Nos. 184/166

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required containment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months atmosphere radioactivity monitor.

SR 3.4.15.2 Perform COT of the required containment atmosphere 92 days radioactivity monitor.

SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required 18 months containment floor and equipment sump level monitoring system.

SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required 18 months containment atmosphere radioactivity monitor.

SR 3.4.15.5 Perform CHANNEL CALIBRATION of the required 18 months containment ventilation condensate drain tank level monitor.

McGuire Units 1 and 2 3.4.15-3 Amendment Nos. 184/166

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS average temperature (T.,g) > 5000 F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT Ad -Note ----

1-131 > 1.0 pCVgm. LCO 3.0.4 is not applicable.

A.1 Verify DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT 1-131 within the acceptable region of Figure 3.4.16-1.

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT 1-131 to within limit.

B. Gross specific activity of B.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months the reactor coolant not T.ag < 500'F.

within limit.

(continued)

McGuire Units 1 and 2 3.4.1 6-1 Amendment Nos. 1841166

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Ta.g < 500'F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable regiofi of Figure 3.4.16-1.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity < 100/E 7 days PCigm.

SR 3.4.16.2 ----------- NOTE-------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 specific 14 days activity < 1.0 pCVgm.

AND Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of > 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

McGuire Units 1 and 2 3.4.1 6-2 Amendment Nos. 184/166

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.16.3 ---- ------ NOTE------- -------

Not required to be performed until 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for > 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine Efrom a sample taken in MODE 1 after a 184 days minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for > 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

McGuire Units 1 and 2 3.4.16-3 Amendment Nos. 184/166

RCS Specific Activity 3.4.16 300 250 I-F o 200 LU 0.

E Z

0n US EL so 0 150) cc ID150

- =

o I-zLU 100 aU LU ul 0

0 50 0

20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER Figure 3.4.16-1 (page 1 of 1)

Reactor Coolant DOSE EQUIVALENT 1-131 Specific Activity Limit Versus Percent of RATED THERMAL POWER McGuire Units 1 and 2 3.4.1 6-4 Amendment Nos. 184/166

RCS Loops - Test Exceptions 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 RCS Loops-Test Exceptions LCO 3.4.17 The requirements of LCO 3.4.4, RCS Loops -MODES 1 and 2," may be suspended, with THERMAL POWER < P-7.

APPLICABILITY: MODES 1 and 2 during startup and PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. THERMAL POWER > A.1 Open reactor trip breakers. Immediately P-7.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify THERMAL POWER is < P-7. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SR 3.4.17.2 Perform a COT for each power range neutron flux-low Prior to initiation of and intermediate range neutron flux channel and P-7. startup and PHYSICS TESTS McGuire Units 1 and 2 3.4.1 7-1 Amendment Nos. 184/166

Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS pressure > 1000 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A.1 Restore boron 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to boron concentration to within concentration not within limits.

limits.

B. One accumulator B.1 Restore accumulator to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable for reasons OPERABLE status.

other than Condition A.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met.

C.2 Reduce RCS pressure to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

< 1000 psig.

D. Two or more D.1 Enter LCO 3.0.3. Immediately accumulators inoperable.

McGuire Units 1 and 2 3.5.1-1 Amendment Nos. 184/166

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.1.2 Verify borated water volume in each accumulator is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

> 6870 gallons and < 7342 gallons.

SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

> 585 psig and < 639 psig.

SR 3.5.1.4 Verify boron concentration in each accumulator is within 31 days the limits specified in the COLR.

AND

NOTE-----

Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of > 1%

of tank volume that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator isolation 31 days valve operator when RCS pressure is > 1000 psig.

McGuire Units 1 and 2 3.5.1 -2 Amendment Nos. 184/166

ECCS-Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS-Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

In MODE 3, both safety injection (SI) pump or RHR pump flow paths may be isolated by closing the isolation valves for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to perform pressure isolation valve testing per SR 3.4.14.1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more trains A.1 Restore train(s) to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units I and 2 3.5.2-1 Amendment Nos. 184/166

ECCS-Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position with 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months power to the valve operator removed.

Number Position Function N1162A Open Si Cold Leg Injection N1121A Closed SI Hot Leg Injection N1152B Closed Si Hot Leg Injection Nl183B Closed RHR Hot Leg Injection NI173A Open RHR Cold Leg Injection N1178B Open RHR Cold Leg Injection Nl100B Open SI Pump RWST Suction FW27A Open RHRIRWST Suction Nl147A Open Si Pump Mini-Flow SR 3.5.2.2 Verify each ECCS manual, power operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify ECCS piping is full of water. 31 days (continued)

McGuire Units 1 and 2 3.5.2-2 Amendment Nos. 184/166

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow path that is 18 months not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.6 Verify each ECCS pump starts automatically on an actual 18 months or simulated actuation signal.

SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, each 18 months position stop is in the correct position.

Centrifugal Charging Safety Injection Pump Injection Throttle Pump Throttle Valve Number Valve Number N1480 N1488 N1481 N1489 N1482 N1490 N1483 N1491 SR 3.5.2.8 Verify, by visual inspection, each ECCS train containment 18 months sump suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.

McGuire Units 1 and 2 3.5.2-3 Amendment Nos. 184/166

ECCS - Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS-Shutdown LCO 3.5.3 One ECCS train shall be OPERABLE.

APPLICABILITY: MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status.

B. Required ECCS B.1 Restore required ECCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months centrifugal charging centrifugal charging subsystem inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months associated Completion Time of Condition B not met.

McGuire Units 1 and 2 3.5.3-1 Amendment Nos. 184/166

ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 - ---------- - NOTE-------------

An RHR train may be considered OPERABLE during pressure isolation valve testing and alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

The following SRs are applicable for all equipment In accordance with required to be OPERABLE: applicable SRs SR 3.5.2.1 SR 3.5.2.7 SR 3.5.2.3 SR 3.5.2.8 SR 3.5.2.4 McGuire Units 1 and 2 3.5.3-2 Amendment Nos. 184/1 66

RWST 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST)

LCO 3.5.4 The RWST shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWST boron A.1 Restore RWST to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months concentration not within OPERABLE status.

limits.

OR RWST borated water temperature not within limits.

B. RWST inoperable for B.1 Restore RWST to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months reasons other than OPERABLE status.

Condition A.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.5.4-1 Amendment Nos. 184/166

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify RWST borated water temperature is > 700 F and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

< 100F.

SR 3.5.4.2 Verify RWST borated water volume is> 372,100 gallons. 7 days SR 3.5.4.3 Verify RWST boron concentration is within the limits 7 days specified in the COLR.

McGuire Units 1 and 2 3.5.4-2 Amendment Nos. 184/166

Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow LCO 3.5.5 Reactor coolant pump seal injection flow shall be < 40 gpm with centrifugal charging pump operating and the charging flow control valve full open.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Seal injection flow not A.1 Adjust manual seal 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within limit. injection throttle valves to give a flow within limit with centrifugal charging pump operating and the charging flow control valve full open.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.5.5-1 Amendment Nos. 184/166

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 Ad ---------- NOTE------NOTE Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at

> 2215 psig and < 2255 psig.

Verify manual seal injection throttle valves are adjusted 31 days to give a flow within limit with centrifugal charging pump operating and the charging flow control valve full open.

McGuire Units 1 and 2 3.5.5-2 Amendment Nos. 184/166

Containment 3.6.1 3.6 CONTAINMENT.SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.1 -1 Amendment Nos. 207 & 188

Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 1

SR 3.6.1.1 --------------------------------- NOTES--------------------------------

1. The space between each dual ply bellows assembly I on penetrations between the containment building and annulus shall be vented to the annulus during Type A tests.

2. Following each Type A test, the space between each dual-ply bellows assembly shall be subjected to a low pressure test at 3 to 5 psig to verify no detectable leakage, or the assembly shall be subjected to a leak test with the pressure on the containment side of the assembly at Pa.

3. Type C tests on penetrations M372 and M373 may be performed without draining the glycol-water mixture from the seats of their diaphragm valves if meeting a zero indicated leakage rate (not including instrument error).

Perform required visual examinations and leakage rate In accordance with testing except for containment airlock testing, in the Containment accordance with the Containment Leakage Rate Testing Leakage Rate Program. Testing Program I

McGuire Units 1 and 2 3.6.1 -2 Amendment Nos. 207 & 188

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 IJIT f%

_____ ______ ------------ I

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

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1, Containment,' when air lock leakage results in exceeding the overall containment leakage rate.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more ----------

containment air locks 1. Required Actions A.1, A.2, with one containment air and A.3 are not applicable lock door inoperable. 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)

McGuire Units 1 and 2 3.6.2-1 Amendment Nos. 184/166

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

AND A.2 Lock the OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected air lock.

AND A.3 ----- NOTE------

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

Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock.

(continued)

McGuire Units 1 and 2 3.6.2-2 Amendment Nos. 184/166

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more --- NOTES ------- ----

containment air locks 1. Required Actions B.1, B.2, with containment air lock and B.3 are not applicable interlock mechanism if both doors in the same inoperable. air lock are inoperable and Condition C is entered.

2. Entry and exit of containment is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE door 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is closed in the affected air lock.

AND B.2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected air lock.

AND B.3 ------ NOTE-------

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

Verify an OPERABLE door Once per 31 days is locked closed in the affected air lock.

(continued)

McGuire Units 1 and 2 3.6.2-3 Amendment Nos. 184/166

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more C.1 Initiate action to evaluate Immediately containment air locks overall containment inoperable for reasons leakage rate per other than Condition A LCO 3.6.1.

or B.

AND C.2 Verify a door is closed in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the affected air lock.

AND C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.2-4 Amendment Nos. 184/166

Containment Air Locks 3.6.2 ACTIONS (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 --------------------------------- NOTE---------------------------------

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rate Testing the Containment Program. Leakage Rate Testing Program.

SR 3.6.2.2 Perform a pressure test on each inflatable air lock door 6 months seal and verify door seal leakage is < 15 sccm.

SR 3.6.2.3 Verify only one door in the air lock can be opened at a 18 months time.

McGuire Units and 2 3.6.2-5 Amendment Nos. 207 & 188

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

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

ACTIONS o ------------------ NOTES-------- I-------

1. Penetration flow path(s) except for containment purge supply and/or exhaust isolation valves for the lower compartment and instrument room may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1, Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. ------NOTE------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to penetration flow path by penetration flow paths use of at least one closed with two containment and de-activated automatic isolation valves. valve, closed manual valve, blind flange, or check valve inside One or more penetration containment with flow flow paths with one through the valve secured.

containment isolation valve inoperable except AND for purge valve or reactor building bypass leakage not within limit.

(continued)

McGuire Units 1 and 2 3.6.3-1 Amendment Nos. 184/166

Containment Isolation Valves 3.6.3 ACTIONS CONDITION 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 Once per 31 days for penetration flow path is isolation devices isolated. outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. ---- NOTE---------- B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path by penetration flow paths use of at least one closed with two containment and de-activated automatic isolation valves. valve, closed manual

-- Ace------ valve, or blind flange.

One or more penetration flow paths with two containment isolation valves inoperable except for purge valve or reactor building bypass leakage not within limit.

(continued)

McGuire Units 1 and 2 3.6.3-2 Amendment Nos. 184/166

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. ------ NOTE------ Ca.1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Only applicable to penetration flow path by penetration flow paths use of at least one closed with only one and de-activated automatic containment isolation valve, closed manual valve and a closed valve, or blind flange.

system.

- -- AND One or more penetration C.2 ----- NOTE----

flow paths with one Isolation devices in high containment isolation radiation areas may be valve inoperable. verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path is isolated.

D. Reactor building bypass D.1 Restore leakage within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months leakage not within limit. limit.

E. One or more penetration E.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months flow paths with one or penetration flow path by more containment purge use of at least one closed valves not within purge and de-activated automatic valve leakage limits. valve, closed manual valve, or blind flange.

AND (continued)

McGuire Units and 2 3.6.3-3 Amendment Nos. 184/166

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.2 ------NOTE---------

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

Verify the affected Once per 31 days for penetration flow path is isolation devices isolated. outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment AND E.3 Perform SR 3.6.3.6 for the Once per resilient seal purge valves 92 days closed to comply with Required Action E.1.

F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.3-4 Amendment Nos. 184/166

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment purge valve for the lower 31 days compartment and instrument room is sealed closed, except for one purge valve in a penetration flow path while in Condition E of this LCO.

SR 3.6.3.2 Verify each containment purge and exhaust isolation 31 days valve for the upper compartment is closed, except when the valves are open for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open.

SR 3.6.3.3 ---- NOTE-------------

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

Verify each containment isolation manual valve and blind 31 days flange that is located outside containment or annulus 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.

(continued)

McGuire Units 1 and 2 3.6.3-5 Amendment Nos. 184/166

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.4 ---------------------------------NOTE---------------------------------

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

Verify each containment isolation manual valve and blind Prior to entering flange that is located inside containment or annulus and MODE 4 from not locked, sealed, or otherwise secured and required to MODE 5 if not be closed during accident conditions is closed, except for performed within containment isolation valves that are open under the previous administrative controls. 92 days SR 3.6.3.5 Verify the isolation time of automatic power operated In accordance with containment isolation valve is within limits. the Inservice Testing Program In accordance with SR 3.6.3.6 Perform leakage rate testing for containment purge lower the Containment and upper compartment and Instrument room valves with Leakage Rate resilient seals. Testing Program SR 3.6.3.7 Verify each automatic containment isolation valve that is 18 months not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

(continued)

McGuire Units 1 and 2 3.6.3-6 Amendment Nos.207 & 188

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued) .-

SURVEILLANCE FREQUENCY In accordance with SR 3.6.3.8 Verify the combined leakage rate for all reactor building the Containment bypass leakage paths is S 0.07 La when pressurized to Leakage Rate

Ž P, 14.8 psig. Testing Program McGuire Units 1 and 2 3.6.3-7 Amendment Nos. 207 & 188

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be 2 -0.3 psig and S +0.3 psig.

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

ACTIONS _ _

CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits. pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.6.4-1 Amendment Nos. 184/166

Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be:

a. 2 75 0F and

100F for the containment upper compartment, and

b. 2 100 0F and

120 0F for the containment lower compartment.

NOTES -- - -- -

1. The minimum containment average air temperature in MODES 2, 3, and 4 may be reduced to 60 0F.

2. Containment lower compartment temperature may be between 120OF and 125 0F for up to 90 cumulative days per calendar year provided lower compartment temperature average over the previous 365 days is less than 120 0F. Within this 90 cumulative day period, lower compartment temperature may be between 125 0F and 135 0F for 72 cumulative hours.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air temperature to limits. within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.5-1 Amendment Nos. 184/166

Containment Air Temperature 3.6.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment upper compartment average air 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months temperature is within limits.

SR 3.6.5.2 Verify containment lower compartment average air 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months temperature is within limits.

, _ .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~

McGuire Units 1 and 2 3.6.5-2 Amendment Nos. 184/166

Containment Spray System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray System LCO 3.6.6 Two containment spray trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment spray A.1 Restore containment spray 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable. train to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power operated, 31 days and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

(continued)

McGuire Units 1 and 2 3.6.6-1 Amendment Nos. 184/166

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)_

SURVEILLANCE FREQUENCY SR 3.6.6.2 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.6.6.3 Verify each automatic containment spray valve in the flow 18 months path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.4 Verify each containment spray pump starts automatically 18 months on an actual or simulated actuation signal.

SR 3.6.6.5 Verify that each spray pump is de-energized and 18 months prevented from starting upon receipt of a terminate signal and is allowed to start upon receipt of a start permissive from the Containment Pressure Control System (CPCS).

SR 3.6.6.6 Verify that each spray pump discharge valve closes or is 18 months prevented from opening upon receipt of a terminate signal and is allowed to open upon receipt of a start permissive from the Containment Pressure Control System (CPCS).

SR 3.6.6.7 Verify each spray nozzle is unobstructed. 10 years McGuire Units 1 and 2 3.6.6-2 Amendment Nos. 184/166

Hydrogen Recombiners 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Hydrogen Recombiners LCO 3.6.7 Two hydrogen recombiners shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One hydrogen A.1 ------ NOTE-recombiner inoperable. LCO 3.0.4 is not applicable.

Restore hydrogen 30 days recombiner to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.6.7-1 Amendment Nos. 184/166

Hydrogen Recombiners 3.6.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Perform a system functional test for each hydrogen 18 months recombiner.

SR 3.6.7.2 Visually examine each hydrogen recombiner enclosure 18 months and verify there is no evidence of abnormal conditions.

SR 3.6.7.3 Perform a resistance to ground test for each heater 18 months phase.

McGuire Units 1 and 2 3.6.7-2 Amendment Nos. 184/166

HSS 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Hydrogen Skimmer System (HSS)

LCO 3.6.8 Two HSS trains shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One HSS train A.1 ---- NOTE-------

inoperable. LCO 3.0.4 is not applicable.

Restore HSS train to 30 days OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.6.8-1 Amendment Nos. 184/166

HSS 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Operate each HSS train for 2 15 minutes. 92 days SR 3.6.8.2 Verify the fan motor current is

21.5 amps when the fan 92 days speed is 2 3579 rpm and < 3619 rpm with the hydrogen skimmer fan operating and the motor operated suction valve closed.

SR 3.6.8.3 Verify the motor operated suction valve opens 92 days automatically and the hydrogen skimmer fans receive a start permissive signal from the Containment Pressure Control System.

SR 3.6.8.4 Verify each HSS train starts on an actual or simulated 92 days actuation signal after a delay of 2 8 minutes and < 10 minutes.

McGuire Units 1 and 2 3.6.8-2 Amendment Nos. 184/166

HMS 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Hydrogen Mitigation System (HMS)

LCO 3.6.9 Two HMS trains shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One HMS train A.1 Restore HMS train to 7 days inoperable. OPERABLE status.

OR A.2 Perform SR 3.6.9.1 on the Once per 7 days OPERABLE train.

B. One containment region B.1 Restore one hydrogen 7 days with no OPERABLE ignitor in the affected hydrogen ignitor. containment region to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

McGuire Units 1 and 2 3.6.9-1 Amendment Nos. 184/166

HMS 3.6.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Energize each HMS train power supply breaker and 92 days verify 2 34 ignitors are energized in each train.

SR 3.6.9.2 Verify at least one hydrogen ignitor is OPERABLE in 92 days each containment region.

SR 3.6.9.3 Energize each hydrogen ignitor and verify temperature is 18 months 2 17000 F.

McGuire Units 1 and 2 3.6.9-2 Amendment Nos. 184/166

AVS 3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Annulus Ventilation System (AVS)

LCO 3.6.1 0 Two AVS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One AVS train A.1 Restore AVS train to 7 days inoperable. OPERABLE status.

B. One or more AVS B.1 Restore AVS train(s) 7 days train(s) heater heater to OPERABLE inoperable. status.

OR B.2 Initiate action in 7 days accordance with Specification 5.6.6.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.1 0-1 Amendment Nos. 184/166

AVS 3.6.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Operate each AVS train for > 10 continuous hours with 31 days heaters operating.

SR 3.6.10.2 Perform required AVS filter testing in accordance with the In accordance with Ventilation Filter Testing Program (VFTP). the VFTP SR 3.6.10.3 Verify each AVS train actuates on an actual or simulated 18 months actuation signal.

SR 3.6.10.4 Verify each AVS filter cooling bypass valve can be 18 months opened.

SR 3.6.10.5 Verify each AVS train flow rate is > 7200 cfm and S 8800 18 months cfm.

McGuire Units 1 and 2 3.6.1 0-2 Amendment Nos. 184/166

ARS 3.6.11 3.6 CONTAINMENT SYSTEMS 3.6.11 Air Return System (ARS)

LCO 3.6.11 Two ARS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ARS train A.1 Restore ARS train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.11.1 Verify each ARS fan starts on an actual or simulated 92 days actuation signal, after a delay of 2 8 minutes and S 10 minutes, and operates for 2 15 minutes.

(continued)

McGuire Units 1 and 2 3.6.1 1-1 Amendment Nos. 184/166

ARS 3.6.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.11.2 Verify, with the ARS fan damper closed and with the 92 days bypass dampers open, each ARS fan motor current is

32.0 amps when the fan speed is 2 840 rpm and

900 rpm.

SR 3.6.11.3 Verify, with the ARS fan not operating, each ARS motor 92 days operated damper opens automatically on an actual or simulated actuation signal after a delay of > 9 seconds and* 11 seconds.

SR 3.6.11.4 Verify the check damper is open with the air return fan 92 days operating.

SR 3.6.11.5 Verify the check damper is closed with the air return fan 92 days not operating.

SR 3.6.11.6 Verify that each ARS fan is de-energized or is prevented 18 months from starting upon receipt of a terminate signal and is allowed to start upon receipt of a start permissive from the Containment Pressure Control System (CPCS).

SR 3.6.11.7 Verify that ARS fan motor-operated damper is allowed to 18 months open upon receipt of a start permissive from the Containment Pressure Control System (CPCS) and is prevented from opening in the absence of a start permissive.

McGuire Units 1 and 2 3.6.11-2 Amendment Nos. 184/166

Ice Bed 3.6.12 3.6 CONTAINMENT SYSTEMS 3.6.12 Ice Bed LCO 3.6.12 The ice bed shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Ice bed inoperable. A.1 Restore ice bed to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.12.1 Verify maximum ice bed temperature is S 271F. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

McGuire Units 1 and 2 3.6.1 2-1 Amendment Nos. 184/166

Ice Bed 3.6.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.12.2 --- ---------------- NOTE------ -------- I The chemical analysis may be performed on either the liquid solution or on the resulting ice.

Verify, by chemical analysis, that ice added to the ice Each ice addition condenser meets the boron concentration and pH requirements of SR 3.6.12.7.

SR 3.6.12.3 Verify by visual inspection, accumulation of ice on 18 months I structural members comprising flow channels through the ice bed is < 15 percent blockage of the total flow area for each safety analysis section.

SR 3.6.12.4 Verify total mass of stored ice is 2 1,890,000 lbs by 18 months calculating the mass of stored ice, at a 95 percent confidence, in each of three Radial Zones as defined below, by selecting a random sample of 2 30 ice baskets in each Radial Zone, and Verify:

1. Zone A (radial rows 8, 9), has a total mass of

> 313,200 lbs

2. Zone B (radial rows 4, 5, 6, 7), has a total mass of 2 901,000 lbs

3. Zone C (radial rows 1, 2, 3), has a total mass of

> 675,800 lbs SR 3.6.12.5 Verify that the ice mass of each basket sampled in SR 18 months 3.6.12.4 is 2 600 lbs.

(continued)

McGuire Units I and 2 3.6.1 2-2 Amendment Nos. 217/199

Ice Bed 3.6.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.12.6 Visually inspect, for detrimental structural wear, cracks, 40 months corrosion, or other damage, two ice baskets from each group of bays as defined below:

a. Group 1 - bays 1 through 8;

b. Group 2 - bays 9 through 16; and

c. Group 3 - bays 17 through 24.

SR 3.6.12.7 ----------------NOTE--------

The requirements of this SR are satisfied if the boron concentration and pH values obtained from averaging the individual sample results are within the limits specified below.

Verify, by chemical analysis of the stored ice in at least 54 months one randomly selected ice basket from each ice condenser bay, that ice bed:

a. Boron concentration is > 1800 ppm and < 2330 ppm; and

b. pH is > 9.0 and 9.5.

McGuire Units 1 and 2 3.6.12-3 Amendment Nos. 217/1 99

Ice Condenser Doors 3.6.13 3.6 CONTAINMENT SYSTEMS 3.6.13 Ice Condenser Doors LCO 3.6.13 The ice condenser inlet doors, intermediate deck doors, and top deck doors shall be OPERABLE and closed.

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

ACTIONS Separate Coditin eNOTE-- sro Separate Condition entry is allowed for each ice condenser door.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more ice A.1 Restore door to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months condenser doors OPERABLE status.

inoperable due to being physically restrained from opening.

B. One or more ice B.1 Verify maximum ice bed Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months condenser doors temperature is

270F.

inoperable for reasons other than Condition A AND or not closed.

B.2 Restore ice condenser door 14 days to OPERABLE status and closed positions.

(continued)

McGuire Units 1 and 2 3.6.1 3-1 Amendment Nos. 184/166

Ice Condenser Doors 3.6.13 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Restore ice condenser door 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months associated Completion to OPERABLE status and Time of Condition B not closed position.

met.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or C AND not met.

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.13.1 Verify all inlet doors indicate closed by the Inlet Door 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Position Monitoring System.

SR 3.6.13.2 Verify, by visual inspection, each intermediate deck door 7 days is closed and not impaired by ice, frost, or debris.

SR 3.6.13.3 Verify, by visual inspection, each top deck door: 92 days

a. Is in place; and

b. Has no condensation, frost, or ice formed on the door that would restrict its opening.

(continued)

McGuire Units 1 and 2 3.6.13-2 Amendment Nos. 184/166

Ice Condenser Doors 3.6.13 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.13.4 Verify, by visual inspection, each inlet door is not 18 months impaired by ice, frost, or debris.

SR 3.6.13.5 Verify torque required to cause each inlet door to begin 18 months to open is S 675 in-lb.

SR 3.6.13.6 Perform a torque test on each inlet door. 18 months SR 3.6.13.7 Verify for each intermediate deck door: 18 months

a. No visual evidence of structural deterioration;

b. Free movement of the vent assemblies; and C. Free movement of the door.

McGuire Units 1 and 2 3.6.13-3 Amendment Nos. 184/166

Divider Barrier Integrity 3.6.14 3.6 CONTAINMENT SYSTEMS 3.6.14 Divider Barrier Integrity LCO 3.6.14 Divider barrier integrity shall be maintained.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ----- NOTE------ A.1 Restore personnel access 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months For this action, separate doors and equipment Condition entry is hatches to OPERABLE allowed for each status and closed personnel access door positions.

or equipment hatch.

One or more personnel access doors or equipment hatches open or inoperable, other than for personnel transit entry.

B. Divider barrier seal B.1 Restore seal to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.1 4-1 Amendment Nos. 184/166

Divider Barrier Integrity 3.6.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.14.1 Verify, by visual inspection, all personnel access doors Prior to entering and equipment hatches between upper and lower MODE 4 from containment compartments are closed. MODE 5 SR 3.6.14.2 Verify, by visual inspection, that the seals and sealing Prior to final surfaces of each personnel access door and equipment closure after each hatch have: opening

a. No detrimental misalignments; AND

b. No cracks or defects in the sealing surfaces; and -----NOTE-----

Only required for

c. No apparent deterioration of the seal material. seals made of resilient materials 10 years SR 3.6.14.3 Verify, by visual inspection, each personnel access door After each or equipment hatch that has been opened for personnel opening transit entry is closed.

SR 3.6.14.4 Remove two divider barrier seal test coupons and verify 18 months both test coupons' tensile strength is Ž 39.7 psi.

(continued)

McGuire Units 1 and 2 3.6.1 4-2 Amendment Nos. 1841166

Divider Barrier Integrity 3.6.14 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.14.5 Visually inspect 2 95% of the divider barrier seal length, 18 months and verify:

a. Seal and seal mounting bolts are properly installed; and

b. Seal material shows no evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical appearance.

McGuire Units 1 and 2 3.6.1 4-3 Amendment Nos. 184/166

Containment Recirculation Drains 3.6.15 3.6 CONTAINMENT SYSTEMS 3.6.15 Containment Recirculation Drains LCO 3.6.15 The ice condenser floor drains and the refueling canal drains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ice condenser floor A.1 Restore ice condenser floor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months drain inoperable. drain to OPERABLE status.

B. One refueling canal B.1 Restore refueling canal 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months drain inoperable. drain to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.6.1 5-1 Amendment Nos. 184/166

Containment Recirculation Drains 3.6.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.15.1 Verify, by visual inspection, that: Prior to entering MODE 4 from

a. Each refueling canal drain valve is locked open; MODE 5 after each partial or

b. Each refueling canal drain is not obstructed by complete fill of the debris; and canal SR 3.6.15.2 Verify, by visual inspection, that no debris is present in 92 days the upper compartment or refueling canal that could obstruct the refueling canal drain.

SR 3.6.15.3 Verify for each ice condenser floor drain that the: 18 months

a. Valve opening is not impaired by ice, frost, or debris;

b. Valve seat shows no evidence of damage;

c. Valve opening force is

66 b; and

d. Drain line from the ice condenser floor to the lower compartment is unrestricted.

McGuire Units 1 and 2 3.6.15-2 Amendment Nos. 184/166

Reactor Building 3.6.16 3.6 CONTAINMENT SYSTEMS 3.6.16 Reactor Building LCO 3.6.16 The reactor building shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor building A.1 Restore reactor building to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.16.1 Verify the door in each access opening is closed, except 31 days I when the access opening is being used for normal transit entry and exit. I (continued)

McGuire Units 1 and 2 3.6.1 6-1 Amendment Nos. 212/193

Reactor Building 3.6.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

.4 SR 3.6.16.2 Verify each Annulus Ventilation System train produces a 18 months on a pressure equal to or more negative than -0.5 inch water STAGGERED gauge in the annulus within 22 seconds after a start TEST BASIS signal and -3.5 Inches water gauge after 48 seconds.

Verifying that upon reaching a negative pressure of -3.5 inches water gauge in the annulus, the system switches Into its recirculation mode of operation and that the time required for the annulus pressure to increase to -0.5 inch water gauge is > 278 seconds.

SR 3.6.16.3 Verify reactor building structural integrity by performing a 3 times every 10 visual Inspection of the exposed interior and exterior years, coinciding surfaces of the reactor building. . with containment visual examinations required by SR 3.6.1.1 McGuire Units and 2 3.6.16-2 Amendment Nos. 212/193

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.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS Separate Condition entry is allowed for each MS

~~

_~~ -- - -- _ _ _ _ _ _ _ __ _ _

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Reduce power to less than 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months MSSVs inoperable. or equal to the applicable

% RTP listed in Table 3.7.1-1.

AND A.2 Reduce the Power Range 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Neutron Flux High Trip Setpoints to the % RTP value listed in Table 3.7.1-1.

(continued)

McGuire Units 1 and 2 3.7.1-1 Amendment Nos. 184/166

MSSVs 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months One or more steam generators with less than two MSSVs OPERABLE.

SURVEILLANCE REQUIREMENTS __=

SURVEILLANCE FREQUENCY SR 3.7.1.1 ---- NOTE----------------

Only required to be performed prior to entry into MODE 2.

In accordance with Verify each required MSSV lift setpoint per Table 3.7.1-2 the Inservice in accordance with the Inservice Testing Program. Testing Program Following testing, lift setting shall be within +1%.

McGuire Units 1 and 2 3.7.1 -2 Amendment Nos. 184/166

MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)

OPERABLE Main Steam Safety Valves versus Maximum Allowable Power Range Neutron Flux High Setpoints in Percent of RATED THERMAL POWER MINIMUM NUMBER OF MAXIMUM ALLOWABLE MSSVs PER STEAM POWER RANGE NEUTRON GENERATOR REQUIRED FLUX OPERABLE HIGH SETPOINTS (% RTP) 4 *58 3 *39 2 < 19 Table 3.7.1-2 (page 1 of 1)

Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING (psig +/- 3%)

STEAM GENERATOR A B C D SV-20 SV-14 SV-8 SV-2 1170 SV-21 SV-15 SV-9 SV-3 1190 SV-22 SV-1 6 SV-10 SV-4 1205 SV-23 SV-17 SV-1 1 SV-5 1220 SV-24 SV-1 8 SV-12 SV-6 1225 McGuire Units 1 and 2 3.7.1-3 Amendment Nos. 184/166

MSIVs 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs)

LCO 3.7.2 Four MSIVs shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 except when MSIVs are closed and de-activated.

ACTIONS _ .

CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIV inoperable in A.1 Restore MSIV to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months MODE 1. OPERABLE status.

B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met.

C. ------- NOTE ------- C.1 Close MSIV. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Separate Condition entry is allowed for each AND MSIV.

C.2 Verify MSIV is closed. Once per 7 days One or more MSIVs inoperable in MODE 2 or3.

(continued)

McGuire Units 1 and 2 3.7.2-1 Amendment Nos. 184/166

MSIVs 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C not AND met.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 - -- -- NOTE------ ---

Only required to be performed prior to entry into MODE 2.

Verify closure time of each MSIV is < 8.0 seconds on an In accordance with actual or simulated actuation signal. the Inservice Testing Program McGuire Units and 2 3.7.2-2 Amendment Nos. 184/166

MFIVs, MFCVs, MFCV's Bypass Valves, and MFW/AFW NBVs 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs), Main Feedwater Control Valves (MFCVs),

MFCV's Bypass Valves and Main Feedwater (MFW) to Auxiliary Feedwater (AFW)

Nozzle Bypass Valves (MFW/AFW NBVs)

LCO 3.7.3 Four MFIVs, four MFCVs, four MFCV's bypass valves, and four MFW/AFW NBVs shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 except when MFIV, MFCV, MFCV's bypass valve or MFW/AFW NBV is closed and de-activated or isolated by a closed manual valve.

ACTIONS Searate-Condition-entryisallowedor e-a-NOT vale Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more MFIVs A.1 Close or isolate MFIV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND A.2 Verify MFIV is closed or Once per isolated. 7 days B. One or more MFCVs B.1 Close or isolate MFCV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND B.2 Verify MFCV is closed or Once per isolated. 7 days (continued)

McGuire Units and 2 3.7.3-1 Amendment Nos. 184/166

MFIVs, MFCVs, MFCV's Bypass Valves, and MFW/AFW NBVs 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more MFCV's C.1 Close or isolate MFCV's 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months bypass valves or bypass valve or MFW/AFW MFW/AFW NBVs NBV.

inoperable.

AND C.2 Verify MFCV's bypass Once per valve or MFW/AFW NBV is 7 days closed or isolated.

D. Two valves in the same D.1 Isolate affected flow path. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flow path inoperable.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the closure time of each MFIV, MFCV, MFCV's In accordance with bypass valve, and MFW/AFW NBV is < 10 seconds on the Inservice an actual or simulated actuation signal. Testing Program McGuire Units 1 and 2 3.7.3-2 Amendment Nos. 184/166

SG PORVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Steam Generator Power Operated Relief Valves (SG PORVs)

LCO 3.7.4 Three SG PORV lines shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required SG PORV A.1 --------NOTE----

line inoperable. LCO 3.0.4 is not applicable.

Restore required SG 7 days PORV line to OPERABLE status.

B. Two or more required B.1 Restore all but 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SG PORV lines one required SG PORV line inoperable. to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 4 without 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reliance upon steam generator for heat removal.

McGuire Units 1 and 2 3.7.4-1 Amendment Nos. 184/166

SG PORVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each SG PORV. 18 months SR 3.7.4.2 Verify one complete cycle of each SG PORV block valve. 18 months McGuire Units 1 and 2 3.7.4-2 Amendment Nos. 184/166

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Three AFW trains shall be OPERABLE.

-___-___-_----------- I1l i 1* -___----- __-

Only one AFW train, which includes a motor driven pump, is required to be OPERABLE in MODE 4.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One steam supply to A.1 Restore steam supply to 7 days turbine driven AFW OPERABLE status.

pump inoperable. AND 10 days from discovery of failure to meet the LCO B. One AFW train B.1 Restore AFW train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable in MODE 1, 2 OPERABLE status.

or 3 for reasons other AND than Condition A.

10 days from discovery of failure to meet the LCO (continued)

McGuire Units 1 and 2 3.7.5-1 Amendment Nos. 184/166

AFW System 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A AND or B not met.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR Two AFW trains inoperable in MODE 1, 2, or 3.

D. Three AFW trains D.1 ------NOTE--

inoperable in MODE 1, LCO 3.0.3 and all other 2, or 3. LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.

Initiate action to restore Immediately one AFW train to OPERABLE status.

E. Required AFW train E.1 Initiate action to restore Immediately inoperable in MODE 4. AFW train to OPERABLE status.

McGuire Units 1 and 2 3.7.5-2 Amendment Nos. 184/166

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 -------- NOTE------- -- - -

Not applicable to automatic valves when THERMAL POWER is < 10% RTP.

Verify each AFW manual, power operated, and automatic 31 days 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.

SR 3.7.5.2 ---------- NOTE--------------- ---

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after 2 900 psig in the steam generator.

Verify the developed head of each AFW pump at the flow In accordance test point is greater than or equal to the required with the Inservice developed head. Testing Program S R 3.7.5.3 ---------- --- OE - - -------- g Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW automatic valve that is not locked, 18 months sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

(continued)

McGuire Units 1 and 2 3.7.5-3 Amendment Nos. 184/166

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

I SURVEILLANCE FREQUENCY I

SR 3.7.5.4 OTI E----- _- ----

1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after 2 900 psig in the steam generator.

2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.

_ _ _ _ _ , _ _ _~~~~~~~~~~~~--

Verify each AFW pump starts automatically on an actual 18 months or simulated actuation signal.

.~~~~~~~~~~~~~~~~~~~~~~

McGuire Units 1 and 2 3.7.5-4 Amendment Nos. 184/166

CCW System 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Component Cooling Water (CCW) System LCO 3.7.6 Two CCW trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CCW train A.1 -------NOTE--------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.4.6, ARCS Loops-MODE 4,w for residual heat removal loops made inoperable by CCW.

Restore CCW train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.7.6-1 Amendment Nos. 184/166

CCW System 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 -- -------------NTE-----------

Isolation of CCW flow to individual components does not render the CCW System inoperable.

Verify each CCW manual, power operated, and 31 days 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.

SR 3.7.6.2 Verify each CCW automatic valve in the flow path 18 months servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.6.3 Verify each CCW pump starts automatically on an actual 18 months or simulated actuation signal.

McGuire Units 1 and 2 3.7.6-2 Amendment Nos. 184/166

NSWS 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Nuclear Service Water System (NSWS)

LCO 3.7.7 Two NSWS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One NSWS train A.1 ----- NOTES------

inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, AC Sources- Operating,'

for emergency diesel generator made inoperable by NSWS.

2. Enter applicable Conditions and Required Actions of LCO 3.4.6, RCS Loops-MODE 4,' for residual heat removal loops made inoperable by NSWS.

Restore NSWS train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

McGuire Units 1 and 2 3.7.7-1 Amendment Nos. 184/166

NSWS 3.7.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 NOTE---------------------

Isolation of NSWS flow to individual components does not render the NSWS inoperable.

Verify each NSWS manual, power operated, and 31 days 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.

SR 3.7.7.2 Verify each NSWS automatic valve in the flow path 18 months servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.7.3 Verify each NSWS pump starts automatically on an 18 months actual or simulated actuation signal.

McGuire Units 1 and 2 3.7.7-2 Amendment Nos. 184/166

SNSWP 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Standby Nuclear Service Water Pond (SNSWP)

LCO 3.7.8 The SNSWP shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SNSWP inoperable. A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify water level of SNSWP is 2 739.5 ft mean sea 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months level.

SR 3.7.8.2 --- -N--- - -----NOTE---

Only required to be performed during the months of July, August, and September.

Verify average water temperature of SNSWP is S 820 F at 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months an elevation of 722 ft. in SNSWP.

(continued)

McGuire Units 1 and 2 3.7.8-1 Amendment Nos. 184/166

SNSWP 3.7.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.8.3 Verify, by visual inspection, no abnormal degradation, 12 months erosion, or excessive seepage of the SNSWP dam.

McGuire Units 1 and 2 3.7.8-2 Amendment Nos. 184/166

CRAVS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Control Room Area Ventilation System (CRAVS)

LCO 3.7.9 Two CRAVS trains shall be OPERABLE.

--- -_ - -d- ---_- - - - - -

- - - --- - --N

_-- - ___- -------------------------- I -------------------------------------------

I The control room boundary may be opened intermittently under administrative control.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRAVS train A.1 Restore CRAVS train to 7 days inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met in MODE 1, 2, 3, or 4. B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE CRAVS Immediately associated Completion train in emergency mode.

Time of Condition A not met in MODE 5 or 6, or OR during movement of irradiated fuel assemblies, or during CORE ALTERATIONS.

(continued)

McGUIRE Units 1 and 2 3.7.9-1 AmendmentNos.187 (Unit 1) 168 (Unit 2)

CRAVS 3.7.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1 Suspend CORE Immediately ALTERATIONS.

AND C.2.2 Suspend movement of Immediately irradiated fuel assemblies.

D. Two CRAVS trains D.1 Suspend CORE Immediately inoperable in MODE 5 ALTERATIONS.

or 6, or during movement of irradiated AND fuel assemblies, or during CORE D.2 Suspend movement of Immediately ALTERATIONS. irradiated fuel assemblies.

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

F. One or more CRAVS F.1 Restore CRAVS train(s) 7 days train(s) heater heater to OPERABLE inoperable. status.

OR F.2 Initiate action in 7 days accordance with Specification 5.6.6.

G. Two CRAVS trains G.1 Restore control room 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months I inoperable due to boundary to OPERABLE inoperable control room status.

boundary in MODE 1, 2, 3,or4.

I McGUIRE Units 1 and 2 3.7.9-2 Amendment Nos. 187 (Unit 1, 168 (Unit 2,

CRAVS 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CRAVS train for 2 10 continuous hours 31 days with the heaters operating.

SR 3.7.9.2 Perform required CRAVS filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP). VFTP SR 3.7.9.3 Verify each CRAVS train actuates on an actual or 18 months simulated actuation signal.

SR 3.7.9.4 Verify one CRAVS train can maintain a positive pressure 18 months on a of 2 0.125 inches water gauge, relative to atmospheric STAGGERED pressure during the pressurization mode of operation at a TEST BASIS makeup flow rate of

2200 cfm.

McGuire Units 1 and 2 3.7.9-3 Amendment Nos. 184/166

CRACWS 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Control Room Area Chilled Water System (CRACWS)

LCO 3.7.1 0 Two CRACWS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRACWS train A.1 Restore CRACWS train to 30 days inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3.. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met in MODE 1, 2,3, or 4. B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE Immediately associated Completion CRACWS train in Time of Condition A not operation.

met in MODE 5 or 6, or during movement of OR irradiated fuel assemblies, or during C.2.1 Suspend CORE Immediately CORE ALTERATIONS. ALTERATIONS.

AND C.2.2 Suspend movement of Immediately irradiated fuel assemblies.

(continued)

McGuire Units 1 and 2 3.7.1 0-1 Amendment Nos. 184/166

CRACWS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACWS trains D.1 Suspend CORE Immediately inoperable in MODE 5 ALTERATIONS.

or 6, or during movement of irradiated AND fuel assemblies, or during CORE D.2 Suspend movement of Immediately ALTERATIONS. irradiated fuel assemblies.

E. Two CRACWS trains E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify the control room temperature is < 900 F. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.7.1 0-2 Amendment Nos. 184/166

ABFVES 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Auxiliary Building Filtered Ventilation Exhaust System (ABFVES)

LCO 3.7.11 Two ABFVES shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ABFVES A.1 Restore ABFVES to 7 days inoperable. OPERABLE status.

B. Two ABFVES B.1 Restore one ABFVES to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.7.11-1 Amendment Nos. 184/166

ABFVES 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each ABFVES for > 15 minutes. 31 days SR 3.7.11.2 Perform required ABFVES filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.11.3 Verify each ABFVES actuates on an actual or simulated 18 months actuation signal.

SR 3.7.11.4 Verify one ABFVES can maintain a pressure 18 months on a

-0.125 inches water gauge in the ECCS pump room STAGGERED area relative to atmospheric pressure during the post TEST BASIS accident mode of operation.

McGuire Units 1 and 2 3.7.1 1-2 Amendment Nos. 184/166

FHVES 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Fuel Handling Ventilation Exhaust System (FHVES)

LCO 3.7.12 The FHVES shall be OPERABLE and in operation.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel building.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. FHVES inoperable. Ad NOTE------

LCO 3.0.3 is not applicable.

A.1 Suspend movement of Immediately irradiated fuel assemblies in the fuel building.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify FHVES in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.7.12.2 Operate FHVES for 2 15 minutes. Prior to movement of irradiated fuel assemblies (continued)

McGuire Units and 2 3.7.12-1 Amendment Nos. 184/166

FHVES 3.7.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.12.3 Perform required FHVES filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.12.4 Verify FHVES can maintain an exhaust flow rate 18 months

> 8000 cfm greater than the supply flow rate.

SR 3.7.12.5 Verify each FHVES filter bypass damper can be closed. 18 months McGuire Units 1 and 2 3.7.1 2-2 Amendment Nos. 184/166

Spent Fuel Pool Water Level 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Spent Fuel Pool Water Level LCO 3.7.13 The spent fuel pool water level shall be 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pool water A.1 ----- NOTE-------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the spent fuel pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the spent fuel pool water level is 2 23 ft above the 7 days top of the irradiated fuel assemblies seated in the storage racks.

McGuire Units and 2 3.7.1 3-1 Amendment Nos. 184/166

Spent Fuel Pool Boron Concentration 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Spent Fuel Pool Boron Concentration LCO 3.7.14 The spent fuel pool boron concentration shall be within the limit specified in the COLR.

APPLICABILITY: When fuel assemblies are stored in the spent fuel pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pool boron Ad NOTES concentration not within LCO 3.0.3 is not applicable.

limit.

A.1 Suspend movement of fuel Immediately assemblies in the spent fuel pool.

AND A.2 Initiate action to restore Immediately spent fuel pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the spent fuel pool boron concentration is within 7 days limit.

McGuire Units 1 and 2 3.7.1 4-1 Amendment Nos. 184/166

Spent Fuel Assembly Storage 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Spent Fuel Assembly Storage LCO 3.7.15 The combination of initial enrichment, burnup and number of Integral Fuel Burnable Absorber (IFBA) rods of each new or spent fuel assembly stored in the spent fuel pool storage racks shall be within the following configurations:

a. New or irradiated fuel may be stored in Region 1A of the spent fuel pool in accordance with these limits:

1. Unrestricted storage of new fuel meeting the criteria of Table 3.7.15-1; or

2. Unrestricted storage of fuel meeting the criteria of Table 3.7.15-2; or

3. Restricted storage in accordance with Figure 3.7.15-1, of fuel which does not meet the criteria of Table 3.7.15-1 or Table 3.7.15-2.

b. New or irradiated fuel may be stored in Region 1B of the spent fuel pool in accordance with these limits:

1. Unrestricted storage of fuel meeting the criteria of Table 3.7.15-4; or

2. Restricted storage in accordance with Figure 3.7.15-2, of fuel which meets the criteria of Table 3.7.15-5; or

3. Checkerboard storage in accordance with Figure 3.7.15-3 of fuel which does not meet the criteria of Table 3.7.15-5.

c. New or irradiated fuel which has decayed at least 16 days may be stored in Region 2A of the spent fuel pool in accordance with these limits:

1. Unrestricted storage of fuel meeting the criteria of Table 3.7.15-7; or

2. Restricted storage in accordance with Figure 3.7.15-4, of fuel which meets the criteria of Table 3.7.15-8; or

3. Checkerboard storage in accordance with Figure 3.7.15-5 of fuel which does not meet the criteria of Table 3.7.15-8.

McGuire Units 1 and 2 3.7.15-1 Amendment Nos. 197/1 78

Spent Fuei Assemoiy Storage 3.7.15

d. New or irradiated fuel which has decayed at least 16 days may be stored in Region 2B of the spent fuel pool in accordance with these limits:

1. Unrestricted storage of fuel meeting the criteria of Table 3.7.15-10; or

2. Restricted storage in accordance with Figure 3.7.15-6, of fuel which meets the criteria of Table 3.7.15-11; or

3. Checkerboard storage in accordance with Figure 3.7.15-7 of fuel which does not meet the criteria of Table 3.7.15-11.

APPLICABILITY: Whenever any fuel assembly is stored in the spent fuel pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 --------- NOTE--------------

LCO not met. LCO 3.0.3 is not applicable.

Initiate action to move the Immediately noncomplying fuel assembly to the correct location.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify by administrative means the planned spent fuel Prior to storing the pool location is acceptable for the fuel assembly being fuel assembly in stored. the spent fuel pool McGuire Units 1 and 2 3.7. 15-2 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-1 (page 1 of 1)

Minimum Qualifying Number of IFBA Rods Versus Initial Enrichment for Unrestricted Region 1A Storage of New Fuel Initial Nominal Enrichment

(% U-235) Number of IFBA Rods 3.78 (or less) 0 4.22 16 4.56 32 4.75 48 50-45 40 o ACCEPTABLE

< For Unrestricted Storage IL/

LL 25 0

20 E15 v / UNACCEPTABLE Z 10 /For Unrestricted Storage 5

0.

3.50 3.75 4.00 4.25 4.50 4.75 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-1 may be qualified for Unrestricted Region 1A storage by means of an analysis using NRC approved methodology to assure that ke. is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-3 Amendment No. 97/1 78

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-2 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Unrestricted Region 1A Storage Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 3.78 (or less) 0 4.00 1.58 4.50 4.92 4.75 6.66 in 94 8-7-

0 6-ACCEPTABLE For Unrestricted Storage z 5-

- 4-

-i 3.

2-UNACCEPTABLE Cl)

For Unrestricted Storage 1-0 3.50 3.75 4.00 4.25 4.50 4.75 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-2 may be qualified for Unrestricted Region 1A storage by means of an analysis using NRC approved methodology to assure that k is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron. Likewise, previously unanalyzed fuel up to a nominal 4.75 weight% U-235 may be qualified for Restricted Region 1A storage by means of an analysis using NRC approved methodology to assure that kn is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-4 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-3 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Region 1A Filler Assemblies Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.76 (or less) 0 2.00 5.12 2.50 13.57 3.00 19.80 3.50 25.85 4.00 31.50 4.50 36.93 4.75 39.54 50 45 I 40 30 41 Z

-J 25 m 20 E 15 Cu 5

O0 2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-3 may be qualified for use as a Region 1A Filler Assembly by means o an analysis using NRC approved methodology to assure that kt is less than 1.0 v.;th no 1or_ and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-5 Amendment Nos. .197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-4 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Unrestricted Region 1B Storage Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.78 (or less) 0 2.00 3.96 2.50 11.35 3.00 17.61 3.50 23.35 4.00 28.86 4.50 34.10 4.75 36.67 50 45 -

E 40

- Ar'r(iFPTAPI a 35- For Unrestricted Storage L30.

Z 25 m 20

-J EO15 mus UNACCEPTABLE u) 10 For Unrestricted Storage 5.

0 2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT. 0U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-4 may be qualified for Unrestricted Region 1B storage by means of an analysis using NRC approved methodology to assure that kent is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-6 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-5 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Restricted Region 1B Storage with Fillers Initial Nominal Enrichment Assembly Burnup

°/ U-235) (GWD/MTU) 2.20 (or less) 0 2.50 3.91 3.00 9.65 3.50 15.04 4.00 19.87 4.50 24.68 4.75 27.01 30

~25-se 0 2s ACCEPTABLE For Restricted Storage Z 15

>; 10 / UNACCEPTABLE A<) 5 / ~~~~~~~~~~~For Restricted Storage (15 0

2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-5 may be qualified for Restricted Region 1 Storage by means of an analysis using NRC approved methodology to assure that ket is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-7 Amendment Nos:. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-6 (page 1of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Region 1B Filler Assemblies Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.44 (or less) 0 2.00 12.68 2.50 20.17 3.00 27.03 3.50 33.35 4.00 39.33 4.50 45.07 4.75 47.89 50 45 ACCEPTABLE E 40 For Use As Filler Assembly 0 35 0D a30~

Z 25 Cc m 20 UNACCEPTABLE

-j For Use As Filler Assembly EO 15 C) 10 Cl) 5-0 2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT. °U-235 NOTES:

Fuel which differs from those designs used to determine the requ!rements of Table 3.7.15-6 may be qualified for use as a Region 18 Filler Assembly by means of an analysis using NRC approved methodology to assure that keti is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-8 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-7 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Unrestricted Region 2A Storage Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.50 (or less) 0.00 2.00 10.50 2.50 17.97 3.00 24.49 3.50 30.55 4.00 36.25 4.50 41.71 4.75 44.39 60 I-,

50 -

ACCEPTABLE (D For Unrestricted Storage 40 -

z 30 -

-J 20 -

UNACCEPTABLE For Unrestricted Storage CO) 10 -

CO) 0 2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-7 may be qualified for Unrestricted Region 2A storage by means of an analysis using NRC approved methodology to assure that kei is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-9 Amendment Nos. 210 & 191

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-8 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Restricted Region 2A Storage with Fillers Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.80 (or less) 0.00 2.00 3.70 2.50 10.30 3.00 16.10 3.50 21.70 4.00 27.00 4.50 32.10 4.75 34.50 40 v 35-F-

0- 30: ACCEPTABLE For Restricted Storage 0D25:

Z 20:

> 15: UNACCEPTABLE

-j For Restricted Storage c 1o On CS 5 0 . . . . I , . .

2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-8 may be qualified for Restricted Region 2A Storage by means of an analysis using NRC approved methodology to assure that kt is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-10 Amendment Nos. 210 & 191

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-9 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Region 2A Filler Assemblies Initial Nominal Enrichment Assembly Burnup

(°/' U-235) (GWD/MTU) 1.15 (or less) 0.00 2.00 20.00 2.50 27.80 3.00 34.60 3.50 41.10 4.00 47.20 4.50 53.10 4.75 55.90 60 *1 ACCEPTABLE

. For Use As Filler Assembly 0

0 40-E-

Z 30:

a:

m UNACCEPTABLE i 20: For Use As Filler Assembly w

L1 n loo CD A _

2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-9 may be qualified for use as a Region 2A Filler Assembly by means of an analysis using NRC approved methodology to assure that ke is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-11 Amendment Nos. 210 & 191

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-10 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Unrestricted Region 2B Storage Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.11 (or less) 0 2.00 21.58 2.50 29.00 3.00 35.69 3.50 41.97 4.00 47.90 4.50 53.57 4.75 56.33 60 D 50 - ACCEPTABLE For Unrestricted Storage 0

40 a-Z 30 -

a)

UNACCEPTABLE

> 20 For Unrestricted Storage m

20 U) 10 0

2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-10 may be qualified for Unrestricted Region 2B storage by means of an analysis using NRC approved methodology to assure that keg isless than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-12 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-11 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Restricted Region 2B Storage with Fillers Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.22 (or less) 0 2.00 17.55 2.50 24.73 3.00 31.31 3.50 37.40 4.00 43.15 4.50 48.65 4.75 51.33 60 D

l 50 ACCEPTABLE For Restricted Storage 30 40:

Z 30 -

UNACCEPTABLE mi 20 For Restricted Storage c

co 1 I I 2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the requirements of Table 3.7.15-11 may be qualified for Restricted Region 2B Storage by means of an analysis using NRC approved methodology to assure that kee is less than 1.0 with no boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1 and 2 3.7.15-13 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 Table 3.7.15-12 (page 1 of 1)

Minimum Qualifying Burnup Versus Initial Enrichment for Region 28 Filler Assemblies Initial Nominal Enrichment Assembly Burnup

(% U-235) (GWD/MTU) 1.08 (or less) 0 2.00 23.14 2.50 30.59 3.00 37.42 3.50 43.74 4.00 49.72 4.50 55.49 4.75 58.33 60 H 50 - ACCEPTABLE For Use As Filler Assembly 0

¢ 40 I 0D Z 30-a:

D UNACCEPTABLE For use AS r!:e, .AssemDly 20 m

0.

0 2.00 2.50 3.00 3.50 4.00 4.50 INITIAL NOMINAL ENRICHMENT, %U-235 NOTES:

Fuel which differs from those designs used to determine the ve-qJ-ements of Table 3.7.15-12 may be qualified for use as a Region 28 Filler Assembly by mean's of an analysis using NRC approved methodology to assure that ki is less than 1.0 wi!t' c boron and less than or equal to 0.95 with credit for soluble boron.

McGuire Units 1and 2 3.7.15-14 Amendment Nos. 197/1178

Spent Fuel Assembly Storage 3.7.15

= II [II LI

[ICTED FILLER FUEL LOCATION L 1-Restricted Fuel: Fuel which does not meet the minimum burnup requirements of either Table 3.7.15-1 or Table 3.7.15. 2. (Fuel which does meet the requirements of Table 3.7.15-1 or Table 3.7.15.2, or non-fuel components, or an empty location may be placed in restricted fuel locations as needed).

Filler Location: Either fuel which meets the minimum burnup requirements of Table 3.7.15-3, or an empty cell.

Boundary Condition: Any Restricted Region A Storage Area row bounded by any other storage area shall contain a combination of restricted fuel assemblies and filler locations arranged such that no restricted fuel assemblies are adjacent to each other. Example: In the figure above, row 1 or column 1can not be adjacent to another storage area, but row 4 or column 4 can be.

Figure 3.7.15-1 (page 1of 1)

Required 3 out of 4 Loading Pattern for Restricted Region IA Storage McGuire Units 1 and 2 3.7.15-15 Amendment Nos. 197/178 1

Spent Fuel Assembly Storage 3.7.15 l F~~~~~~~~~~~~~~~~~~~~~~~

I FILLER 4LOCATION FialE I LOCATION

'~~

' EF FILLER FILLER LOCATION ,LOCATION:

Restricted Fuel: Fuel which meets the minimum burnup requirements of Table 3.7.15-5, or non-fuel components, or an empty location.

Filler Location: Either fuel which meets the minimum burnup requirements of Table 3.7.15-6, or an empty cell.

Boundary Condition: Any Restricted Region 1B Storage Area must be separated from any other storage area by at least one row of 1B Filler Locations or empty cells, at all boundaries between storage regions.

Figure 3.7.15-2 (page 1 of 1)

Required 2 out of 4 Loading Pattern for Restricted Region 1B Storage McGuire Units 1 and 2 3.7.15-16 Amendment Nos. 210 & 191

Spent Fuel Assembly Storage 3.7.15 I~~~~~~

EMPTY EMPTY CELL CELL EMPTY EMPTY CELL CELL EMPTY CHECKERBOAR EMPTY CELL FUEL CELL II EMPTY lHECKERBOAF d EMPTY HECKERBOARd CELL 1' E I' CELL FUEL I I' - I1 Checkerboard Fuel: Fuel which does not meet the minimum burnup requirements of Table 3.7.15-5. (Fuel which does meet the requirements of Table 3.7.15-5, or non-fuel components, or an empty location may be placed in checkerboard fuel locations as needed)

Boundary Condition: Any Checkerboard Region 1B Storage Area must be separated from any other storage area by at least one row of empty cells, at all boundaries between storage regions.

Figure 3.7.15-3 (page 1 of 1)

Required 2 out of 4 Loading Pattern for Checkerboard Region B Storage McGuire Units and 2 3.7.1 5-17 Amendment Nos. 210 & 191

Spent Fuel Assembly Storage 3.7.15 FILLER LOCATION FILLER LOCATION A=

FILLER FILLER LOCATION LOCATION

_ i x Restricted Fuel: Fuel which meets the minimum burnup requirements of Table 3.7.15-8, or non-fuel components, or an empty location.

Filler Location: Either fuel which meets the minimum burnup requirements of Table 3.7.15-9, or an empty cell.

Boundary Condition: At least three of the four faces of each 2A Restricted Fuel Assembly must be adjacent to a 2A Filler Location, an empty cell, or the pool wall, at all boundaries between storage regions.

Figure 3.7.15-4 (page 1 of 1)

Required 2 out of 4 Loading Pattern for Restricted Region 2A Storage McGuire Units 1 and 2 3.7.15-18 Amendment Nos. 2 1 0 & 191

Spent Fuel Assembly Storage 3.7.15 l

EMPTY CELL EMPTY HECKERBOAR CELL FUEL FU EL .

EMPTY EMPTY CELL CELL EMPTY EMPTY CELL CELL Checkerboard Fuel: Fuel which does not meet the minimum burnup requirements of Table 3.7.15-8. (Fuel which does meet the requirements of Table 3.7.15-8, or non-fuel components, or an empty location may be placed in checkerboard fuel locations as needed)

Boundary Condition: At least three of the four faces of each Checkerboard Fuel Assembly must be adjacent to an empty cell or the pool wall, at all boundaries between storage regions.

Figure 3.7.15-5 (page 1 of 1)

Required 2 out of 4 Loading Pattern for Checkerboard Region 2A Storage McGuire Units 1 and 2 3.7.15-19 Amendment Nos. 210 & 191

Spent Fuel Assembly Storage 3.7.15 Restricted Fuel: Fuel which meets the minimum burnup requirements of Table 3.7.15-11, or non-fuel components. or an empty location.

Filler Location: Either fuel which meets the minimum burnup requirements of Table 3.7.15-12, or an empty cell.

Boundary Condition: Any Restricted Region 2B Storage Area row bounded by any other storage area shall contain only filler locations arranged such that no Restricted Fuel assemblies are adjacent to any other fuel except Region 2B Filler Locations. Example: In the figure above, row 1 or column 1 can not be adjacent to another storage area, but row 4 or column 4 can be.

Figure 3.7.15-6 (page 1 of 1)

Required 1 out of 4 Loading Pattern for Restricted Region 2B Storage McGuire Units 1 and 2 3.7.1 5-20 Amendment Nos. 197/178

Spent Fuel Assembly Storage 3.7.15 EMPTY CELL EMPTY EMPTY EMPTY EMPTY CELL CELL CELL CELL HECKERBOARD EMPTY EMPTY FUEL CELL CELL l I EMPTY EMPTY EMPTY CELL CELL CELL Checkerboard Fuel: Fuel which does not meet the minimum burnup requirements of Table 3.7.15-11. (Fuel which does meet the requirements of Table 3.7.15-11, or non-fuel components, or an empty location may be placed in checkerboard fuel locations as needed)

Boundary Condition: Any Checkerboard Region 2B Storage Area row bounded by any other storage area shall contain only empty cells arranged such that no Checkerboard Fuel assemblies are adjacent to any fuel. Example: In the figure above, row 1 or column 1 can not be adjacent to another storage area, but row 4 or column 4 can be.

Figure 3.7.15-7 (page 1 of 1)

Required 1 out of 4 Loading Pattern for Checkerboard Region 2B Storage McGuire Units 1 and 2 3.7.1 5-21 Amendment Nos. 197/178

Secondary Specific Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Specific Activity LCO 3.7.16 The specific activity of the secondary coolant shall be 0. 10 IuCi/gm DOSE EQUIVALENT 1-131.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months within limit.

AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the secondary coolant is 31 days

0.10 .tCVgm DOSE EQUIVALENT 1-131.

McGuire Units 1 and 2 3.7.1 6-1 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the off site transmission network and the Onsite Essential Auxiliary Power System; and

b. Two diesel generators (DGs) capable of supplying the Onsite Essential Auxiliary Power Systems; AND The automatic load sequencers for Train A and Train B shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE offsite circuit.

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Declare required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from with no off site power discovery of no available inoperable when offsite power to one its redundant required train concurrent with feature(s) is inoperable. inoperability of redundant required feature(s)

AND (continued)

McGuire Units 1 and 2 3.8.1-1 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Restore offsite circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

AND 6 days from discovery of failure to meet LCO B. One DG inoperable. B.1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months offsite circuit(s).

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.2 Declare required feature(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from supported by the discovery of inoperable DG inoperable Condition B when its required concurrent with redundant feature(s) is inoperability of inoperable. redundant required feature(s)

AND B.3.1 Determine OPERABLE DG 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE DG.

AND (continued)

McGuire Units 1 and 2 3.8.1 -2 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.4 Restore DG to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months status.

AND 6 days from discovery of failure to meet LCO C. Two offsite circuits C.1 Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from inoperable. inoperable when its discovery of redundant required Condition C feature(s) is inoperable. concurrent with inoperability of redundant required feature(s)

AND C.2 Restore one offsite circuit 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to OPERABLE status.

(continued)

McGuire Units 1 and 2 3.8.1-3 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One offsite circuit ------ NOTE-----

inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, AND 'Distribution Systems -

Operating,' when Condition D is One DG inoperable. entered with no AC power source to any train.

D.1 Restore offsite circuit to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

OR D.2 Restore DG to OPERABLE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months status.

E. Two DGs inoperable. E.1 Restore one DG to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

F. One automatic load F.1 Restore automatic load 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sequencer inoperable. sequencer to OPERABLE status.

G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B AND C, D, E, or F not met.

G.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. Three or more AC H.1 Enter LCO 3.0.3. Immediately sources inoperable.

McGuire Units 1 and 2 3.8.1-4 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power 7 days availability for each offsite circuit.

SR 3.8.1.2 ------ -------- NOTES-----

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.

Verify each DG starts from standby conditions and 31 days achieves steady state voltage > 3740 V and

4580 V, and frequency 2 58.8 Hz and

61.2 Hz.

(continued)

McGuire Units 1 and 2 3.8.1-5 Amendment Nos. 1841166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 ~~---------NOTES----------

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

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded and operates 31 days for 2 60 minutes at a load 2 3600 kW and < 4000 kW.

SR 3.8.1.4 Verify each day tank contains 2120 gal of fuel oil. 31 days SR 3.8.1.5 Check for and remove accumulated water from each day 31 days tank.

SR 3.8.1.6 Verify the fuel oil transfer system operates to 31 days automatically transfer fuel oil from storage tank to the day tank.

(continued)

McGuire Units 1 and 2 3.8.1-6 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY I1I ^FT SR 3.8.1.7 _________________________ U J I;j All DG starts may be preceded by an engine prelube period.

-~~ ~~~ --- - -- - -- - -_ - - - -

Verify each DG starts from standby condition and 184 days achieves in

11 seconds voltage of 2 3740 V and frequency of 2 57 Hz and maintains steady state voltage

Ž 3740 V and

4580 V, and frequency 2 58.8 Hz and

61.2 Hz.

SR 3.8.1.8 ---------- NOTES-------------

This Surveillance shall not be performed in MODE 1 or 2.

Verify automatic and manual transfer of AC power 18 months sources from the normal offsite circuit to each alternate offsite circuit.

(continued)

McGuire Units 1 and 2 3.8.1 -7 Amendment Nos. 184/166

AC Sources - Operating

3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

-4 SR 3.8.1.9 Verify each DG, when connected to its bus in parallel with 18 months offsite power and operating with maximum kVAR loading that offsite power conditions permit, rejects a load greater than or equal to its associated single largest post-accident load, and:

a. Following load rejection, the frequency is < 63 Hz;

b. Within 3 seconds following load rejection, the voltage is 2 3740 V and < 4580 V; and

c. Within 3 seconds following load rejection, the frequency is > 58.8 Hz and < 61.2 Hz.

SR 3.8.1.10 Verify each DG does not trip and voltage is maintained 18 months I

' 4784 V during and following a load rejection of 2 3600 kW and

4000 kW.

(continued)

McGuire Units 1 and 2 3.8.1-8 Amendment Nos. 192 (Unittl) 173 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY I.

SR 3.8.1.11 --- ~~--- ---- NOTES---- -------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify on an actual or simulated loss of offsite power 18 months signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes the emergency bus in

< 11 seconds,

2. energizes auto-connected blackout loads through automatic load sequencer,

3. maintains steady state voltage

> 3740 V and *4580 V,

4. maintains steady state frequency

> 58.8 Hz and

61.2 Hz, and

5. supplies auto-connected blackout loads for 2 5 minutes.

(continued)

McGuire Units 1 and 2 3.8.1 -9 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ------- N T S---i---

All DG starts may be preceded by prelube period.

Verify on an actual or simulated Engineered Safety 18 months Feature (ESF) actuation signal each DG auto-starts from standby condition and:

a. In

11 seconds after auto-start signal achieves voltage of 2 3740 and during tests, achieves steady state voltage 2 3740 V and s 4580 V;

b. In s 11 seconds after auto-start signal achieves frequency of 2 57 Hz and during tests, achieves steady state frequency 58.8 Hz and 5 61.2 Hz;

c. Operates for 2 5 minutes; and

d. The emergency bus remains energized from the offsite power system.

(continued)

McGuire Units 1 and 2 3.8.1 -10 Amendment Nos. 184/166

AC Sources - Operating i.3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 Verify each DG's automatic trips are bypassed on actual 18 months or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except:

a. Engine overspeed;

b. Generator differential current;

c. Low lube oil pressure; and

d. Generator voltage - controlled overcurrent.

SR 3.8.1.14 N O TES

1. Momentary transients outside the load range do not invalidate this test.

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

Verify each DG, when connected to its bus in parallel with 18 months offsite power and operating with maximum kVAR loading that offsite power conditions permit, operates for 2 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a. For 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 4200 kW and

4400 kW; and

b. For the remaining hours of the test loaded 2 3600 kW and

4000 kW.

(continued)

McGuire Units 1 and 2 3.8.1-11 Amendment Nos. 192 (Unit 1) 173 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

.4 SR 3.8.1.15 - --- ------ -- ---- NOTES---------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 3600 kW and

< 4000 W.

Momentary transients outside of load range do not invalidate this test.

2. All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves, in 11 seconds, 18 months voltage > 3740 V, and frequency 57 Hz and maintains steady state voltage 2 3740 V and

4580 V and frequency Ž 58.8 Hz and

61.2 Hz.

&IrTWr-e%

SR 3.8.1.16 A-----a------- ^-NU I b___ A_________

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify each DG: 18 months

a. Synchronizes with off site power source while loaded with emergency loads upon a simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to standby operation.

(continued)

McGuire Units 1 and 2 3.8.1 -12 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17 ---- ---- NOTES----a-----

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify, with a DG operating in test mode and connected 18 months to its bus, an actual or simulated ESF actuation signal overrides the test mode by:

a. Returning DG to standby operation; and

b. Automatically energizing the emergency load from offsite power.

SR 3.8.1.18 Verify interval between each sequenced load block is 18 months within design interval for each automatic load sequencer.

(continued)

McGuire Units 1 and 2 3.8.1 -13 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 --------------------NOTES--------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1,2, 3, or4.

Verify on an actual or simulated loss of offsite power 18 months signal in conjunction with an actual or simulated ESF actuation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and:

1. energizes the emergency bus in

11 seconds,

2. energizes auto-connected emergency loads through load sequencer,

3. achieves steady state voltage 2 3740 V and 4580 V,

4. achieves steady state frequency 2 58.8 Hz and

61.2 Hz, and

5. supplies auto-connected emergency loads for 5 minutes.

(continued)

McGuire Units 1 and 2 3.8.1 -14 Amendment Nos. 184/166

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 ------ NOTES--------------------

All DG starts may be preceded by an engine prelube period.

Verify when started simultaneously from standby 10 years condition, each DG achieves, in

11 seconds, voltage of

Ž 3740 V and frequency of > 57 Hz and maintains steady state voltage 2 3740 V and S 4580 V, and frequency

> 58.8 Hz and S 61.2 Hz.

McGuire Units 1 and 2 3.8.1 -15 Amendment Nos. 184/166

AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources-Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the Onsite Essential Auxiliary Power distribution system required by LCO 3.8.10, Distribution Systems -Shutdownu; and

b. One diesel generator (DG) capable of supplying one train of the Onsite Essential Auxiliary Power distribution system required by LCO 3.8.10.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite NOTE-------

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.1 Declare affected required Immediately feature(s) with no offsite power available inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND (continued)

McGuire Units 1 and 2 3.8.2-1 Amendment Nos. 184/166

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or required boron concentration.

AND A.2.4 Initiate action to restore Immediately required offsite power circuit to OPERABLE status.

B. One required DG B.1 Suspend CORE Immediately inoperable. ALTERATIONS.

AND B.2 Suspend movement of Immediately irradiated fuel assemblies.

AND B.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or required boron concentration.

AND B.4 Initiate action to restore Immediately required DG to OPERABLE status.

McGuire Units 1 and 2 3.8.2-2 AmendmentNos. 216 & 197

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 ._ _ _ __ ___ Alp tb ---- -__________

The following SRs are not required to be performed:

SR 3.8.1.3, SR 3.8.1.9, SR 3.8.1.10, SR 3.8.1.1 1, SR 3.8.1.13, SR 3.8.1.14, SR 3.8.1.15, SR 3.8.1.16, and SR 3.8.1.1 8.

For AC sources required to be OPERABLE, the following In accordance with SRs are applicable: applicable SRs SR 3.8.1.1 SR 3.8.1.6 SR 3.8.1.13 SR 3.8.1.2 SR 3.8.1.7 SR 3.8.1.14 SR 3.8.1.3 SR 3.8.1.9 SR 3.8.1.15 SR 3.8.1.4 SR 3.8.1.10 SR 3.8.1.16 SR 3.8.1.5 SR 3.8.1.11 SR 3.8.1.18 McGuire Units and 2 3.8.2-3 Amendment Nos. 184/166

Diesel Fuel Oil and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil and Starting Air LCO 3.8.3 The stored diesel fuel oil and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

~~~~~~-

ktIArCr lNU I --- _-_______________

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.1 Restore fuel oil level to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months fuel oil inventory within limits.

< 39,500 gal and

> 31,600 gal.

B. One or more DGs with B.1 Restore fuel oil total 7 days stored fuel oil total particulates within limit.

particulates not within limit.

C. One or more DGs with C.1 Restore stored fuel oil 30 days new fuel oil properties properties to within limits.

not within limits.

(continued)

McGuire Units 1 and 2 3.8.3-1 Amendment Nos. 184/166

Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with D.1 Initiate action to isolate the Immediately 1 of 2 starting air degraded starting air receiver pressures receiver.

< 210 psig.

AND D.2 Restore both starting air 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months receiver pressures to > 210 psig.

E. Required Action and E.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs diesel fuel oil or starting air subsystem not within limits for reasons other than Condition A, B, C, or D.

McGuire Units 1 and 2 3.8.3-2 Amendment Nos. 184/166

Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify the fuel oil storage system contains Ž 39,500 gal of 31 days fuel for each DG.

SR 3.8.3.2 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.3 Verify each DG air start receiver pressure is Ž 210 psig. 31 days SR 3.8.3.4 Check for and remove accumulated water from the fuel 31 days oil storage tank.

I McGuire Units 1 and 2 3.8.3-3 Amendment Nos. 215 & 196

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources-Operating LCO 3.8.4 The four channels of DC sources shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel of DC A.1 Restore channel of DC 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months source inoperable. source to OPERABLE status.

OR A.2.1 Verify associated bus tie 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months breakers are closed between DC channels.

AND A.2.2 Restore channel of DC 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months source to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months McGuire Units 1 and 2 3.8.4-1 Amendment Nos. 184/166

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is 2 125 V on float charge. 7 days SR 3.8.4.2 Verify no visible corrosion at battery terminals and 92 days connectors.

OR Verify connection resistance of these items is

1.5 E-4 ohm.

SR 3.8.4.3 Verify battery cells, cell plates, and racks show no visual 18 months indication of physical damage or abnormal deterioration that could degrade battery performance.

SR 3.8.4.4 Remove visible terminal corrosion, verify battery cell to 18 months cell and terminal connections are clean and tight, and are coated with anti-corrosion material.

SR 3.8.4.5 Verify battery connection resistance is < 1.5 E-4 ohm for 18 months inter-cell connections, and

1.5 E-4 ohm for terminal connections.

SR 3.8.4.6 Verify each battery charger supplies Ž 400 amps at 18 months 2 125 V for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

(continued)

McGuire Units 1 and 2 3.8.4-2 Amendment Nos. 184/166

DC Sources - Operating 3.8.4 SURVEILLANCE FREQUENCY SR 3.8.4.7 --------------------------------------------

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. I Verify battery capacity is adequate to supply, and 18 months maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

SR 3.8.4.8 Verify battery capacity is 2 80% of the manufacturer's 60 months rating when subjected to a performance discharge test or a modified performance discharge test. AND 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100%

of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity >

100% of manufacturer's rating McGuire Units 1 and 2 3.8.4-3 Amendment Nos. 209 & 190

DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 The following shall be OPERABLE:

a. Two channels of DC sources capable of supplying one train of the DC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems Shutdown," and

b. One source of DC electrical power, other than that required by LCO 3.8.5.a, capable of supplying the remaining train of the DC electrical power distribution subsystem(s) when required by LCO 3.8.10.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1.1 Declare affected required Immediately channel(s) of DC feature(s) inoperable.

source(s) inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND (continued)

McGuire Units 1 and 2 3.8.5-1 Amendment Nos. 184/166

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or required boron concentration.

AND A.2.4 Initiate action to restore Immediately required channel(s) of DC source(s) to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 --------- ----- 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 following In accordance with SRs are applicable: 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 McGuire Units 1 and 2 3.8.5-2 Amendment Nos. 216 & 197

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for the channels of DC batteries shall be within the limits of Table 3.8.6-1.

APPLICABILITY: When associated channels of DC sources are required to be OPERABLE.

ACTIONS r-Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries A.1 Verify pilot cells electrolyte 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one or more battery level and float voltage cell parameters not meet Table 3.8.6-1 within Category A or B Category C limits.

limits.

AND A.2 Verify battery cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months parameters meet Table 3.8.6-1 Category C AND limits.

Once per 7 days thereafter AND A.3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6-1.

(continued)

McGuire Units 1 and 2 3.8.6-1 Amendment Nos. 184/166

Battery Cell Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated battery Immediately associated Completion inoperable.

Time of Condition A not met.

OR One or more batteries with average electrolyte temperature of the representative cells

< 601F.

OR One or more batteries with one or more battery cell parameters not within Category C values.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 7 days Category A limits.

(continued)

McGuire Units 1 and 2 3.8.6-2 Amendment Nos. 184/166

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY J.

SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 92 days Category B limits.

AND Once within 7 days after a battery discharge

< 110V AND Once within 7 days after a battery overcharge

>150 V SR 3.8.6.3 Verify average electrolyte temperature of representative 92 days cells is > 600 F.

McGuire Units 1 and 2 3.8.6-3 Amendment Nos. 184/166

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)

Battery Cell Parameters Requirements CATEGORY A: CATEGORY C:

LIMITS FOR EACH CATEGORY B: ALLOWABLE DESIGNATED LIMITS FOR EACH LIMITS FOR EACH PARAMETER PILOT CELL CONNECTED CELL CONNECTED CELL Electrolyte Level > Minimum level > Minimum level Above top of plates, indication mark, and indication mark, and and not overflowing

< Y/4inch above < inch above maximum level maximum level indication mark(a) indication mark(a)

Float Voltage 2 2.13 V > 2.13 V > 2.07 V Specific Gravity(b)(C) 2 1.200 > 1.195 Not more than 0.020 below average of all AND connected cells or> 1.195 Average of all connected cells AND

> 1.205 Average of all connected cells 21.195 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum during equalizing charges provided it is not overflowing.

(b) Corrected for electrolyte temperature and level. Level correction is not required, however, when battery charging is < 2 amps when on float charge.

(c) A battery charging current of < 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

McGuire Units 1 and 2 3.8.6-4 Amendment Nos. 184/166

Inverters - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters-Operating LCO 3.8.7 The four required Channels of inverters shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One inverter inoperable. A.1 ------- NOTE-----

Enter applicable Conditions and Required Actions of LCO 3.8.9,

Distribution Systems - Operating" with any vital bus de-energized.

Restore inverter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, and alignment to required 7 days AC vital buses.

McGuire Units 1 and 2 3.8.7-1 Amendment Nos. 184/166

Inverters - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters-Shutdown LCO 3.8.8 The following shall be OPERABLE:

a. Two inverters capable of supplying one train of the onsite Class 1E AC vital bus electrical power distribution subsystem(s) required by LCO 3.8.10, Distribution Systems-Shutdown," and

b. One source of AC vital bus power, other than that required by LCO 3.8.8.a, capable of supplying the remaining onsite Class 1E AC vital bus electrical power distribution subsystem(s) when required by LCO 3.8.10.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected required Immediately AC vital bus power feature(s) inoperable.

sources inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND (continued)

McGuire Units 1 and 2 3.8.8-1 Amendment Nos. 184/166

Inverters - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or required boron concentration.

AND A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct voltage and alignments to required AC vital 7 days buses.

McGuire Units 1 and 2 3.8.8-2 Amendment Nos.216 & 197

Distribution Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems-Operating LCO 3.8.9 Train A and Train B AC, four channels of DC, and four AC vital buses electrical power distribution subsystems shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more AC A.1 Restore AC electrical 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months electrical power power distribution distribution subsystem(s) subsystem(s) to AND inoperable. OPERABLE status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO B. One AC vital bus B.1 Restore AC vital bus 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable. subsystem to OPERABLE status. AND 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO (continued)

McGuire Units 1 and 2 3.8.9-1 Amendment Nos. 184/166

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One channel of DC C.1 Restore DC channel of 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power electrical power distribution distribution subsystem subsystem to OPERABLE AND inoperable. status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO D. Required Action and DA Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Two trains with E.1 Enter LCO 3.0.3. Immediately inoperable distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to AC, DC, 7 days and AC vital bus electrical power distribution subsystems.

McGuire Units 1 and 2 3.8.9-2 Amendment Nos. 184/166

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 bus electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC, DC, or AC vital bus supported required electrical power feature(s) inoperable.

distribution subsystems inoperable. OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or required boron concentration.

AND (continued)

McGuire Units 1 and 2 3.8.1 0-1 Amendment Nos. 216 & 197

Distribution Systems - Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to restore Immediately required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

AND A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

AND A.2.6 Declare affected Low Immediately Temperature Overpressure Protection (LTOP) feature(s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required 7 days AC, DC, and AC vital bus electrical power distribution subsystems.

McGuire Units 1 and 2 3.8.1 0-2 Amendment Nos. 184/166

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, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. ALTERATIONS.

AND A.2 Suspend positive reactivity Immediately additions.

AND A.3 Initiate action to restore Immediately boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months COLR.

McGuire Units 1 and 2 3.9.1-1 Amendment Nos. 184/166

Unborated Water Source Isolation Valves 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Isolation Valves LCO 3.9.2 Each valve used to isolate unborated water sources shall be secured in the closed position.

APPLICABILITY: MODE 6.

ACTIONS K IFIf- I

NU~~~~~~~

Separate Condition entry is allowed for each unborated water source isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. ------ NOTE------ A.1 Suspend CORE Immediately Required Action A.3 ALTERATIONS.

must be completed whenever Condition A is AND entered.

A.2 Initiate actions to secure Immediately valve in closed position.

One or more valves not secured in closed AND position.

A.3 Perform SR 3.9.1.1. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water sources 31 days is secured in the closed position.

McGuire Units and 2 3.9.2-1 Amendment Nos. 184/166

Nuclear Instrumentation 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Nuclear Instrumentation LCO 3.9.3 Two source range neutron flux monitors shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required source A.1 Suspend CORE Immediately range neutron flux ALTERATIONS.

monitor inoperable.

AND A.2 Suspend operations that Immediately would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

B. Two required source B.1 Initiate action to restore Immediately range neutron flux one source range neutron monitors inoperable. flux monitor to OPERABLE status.

AND B.2 Perform SR 3.9.1.1. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months McGuire Units 1 and 2 3.9.3-1 AmendmentNos. 216 & 197

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.9.3.2 --------------------NOTE--------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months McGuire Units 1 and 2 3.9.3-2 Amendment Nos. 184/166

Containment Penetrations 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Containment Penetrations LCO 3.9.4 The containment penetrations shall be in the following status:

a. The equipment hatch closed and held in place by a minimum of four bolts;

b. A minimum of one door in each air lock closed; and

c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. exhausting through an OPERABLE Containment Purge Exhaust System HEPA filter and charcoal adsorber.

APPLICABILITY: During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Suspend CORE Immediately containment ALTERATIONS.

penetrations not in required status. AND A.2 Suspend movement of Immediately irradiated fuel assemblies within containment.

McGuire Units 1 and 2 3.9.4-1 Amendment Nos. 184/166

Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment penetration is in the 7 days required status.

SR 3.9.4.2 Perform required Containment Purge Exhaust System In accordance with Testing in accordance with the Ventilation Filter Testing the VFTP Program (VFTP).

McGuire Units 1 and 2 3.9.4-2 Amendment Nos. 184/166

RHR and Coolant Circulation - High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation-High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation.

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

The required RHR loop may be removed from operation for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period, provided no operations are permitted that would cause introduction of coolant into the Reactor Coolant System with boron concentration less than required to meet the minimum required boron concentration of LCO 3.9.1.

APPLICABILITY: MODE 6 with the water level > 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RHR loop requirements A.1 Suspend operations that Immediately not met. would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1 AND A.2 Suspend loading irradiated Immediately fuel assemblies in the core.

AND A.3 Initiate action to satisfy Immediately RHR loop requirements.

AND (continued)

McGuire Units 1 and 2 3.9.5-1 Amendment Nos.216 & 197

RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of 2 1000 gpm and RCS temperature is < 1400 F.

McGuire Units 1 and 2 3.9.5-2 Amendment Nos. 184/166

RHR and Coolant Circulation - Low Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation-LowWater Level LCO 3.9.6 Two RHR loops shall be OPERABLE, and one RHR loop shall be in operation.

APPLICABILITY: MODE 6 with the water level < 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A.1 Initiate action to restore Immediately number of RHR loops required RHR loops to OPERABLE. OPERABLE status.

OR A.2 Initiate action to establish Immediately 2 23 ft of water above the top of reactor vessel flange.

B. No RHR loop in B.1 Suspend operations that Immediately operation. would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

AND (continued)

McGuire Units 1 and 2 3.9.6-1 Amendment Nos. 216 & 197

RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to restore Immediately one RHR loop to operation.

AND B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of 2 1000 gpm and RCS temperature is < 140 0F.

SR 3.9.6.2 Verify correct breaker alignment and indicated power 7 days available to the required RHR pump that is not in operation.

McGuire Units 1 and 2 3.9.6-2 Amendment Nos. 184/166

Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained 2 23 ft above the top of reactor vessel flange.

APPLICABILITY: During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.1 Suspend CORE Immediately level not within limit. ALTERATIONS.

AND A.2 Suspend movement of Immediately irradiated fuel assemblies within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water level is 2 23 ft above the top 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of reactor vessel flange.

McGuire Units 1 and 2 3.9.7-1 Amendment Nos. 184/166

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The McGuire Nuclear Station site is located at latitude 35 degrees, 25 minutes, 59 seconds north and longitude 80 degrees, 56 minutes, 55 seconds west. The Universal Transverse Mercator Grid Coordinates are E 504, 669, 256, and N 3, 920, 870, 471.

The site is in northwestern Mecklenburg County, North Carolina, 17 miles north-northwest of Charlotte, North Carolina.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 193 fuel assemblies. Each assembly shall consist of a matrix of Zircalloy fuel rods with an initial composition of natural or slightly enriched uranium dioxide (U0 2) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 53 control rod assemblies. The control material shall be silver indium cadmium (Unit 1) silver indium cadmium and boron carbide (Unit 2) as approved by the NRC.

4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum nominal U-235 enrichment of 4.75 weight percent;

b. kff < 1.0 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the UFSAR;

c. ke,, < 0.95 if fully flooded with water borated to 850 ppm, which includes an allowance for uncertainties as described in Section 9.1 of the UFSAR; McGuire Units 1 and 2 4.0-1 Amendment Nos. 210 & 191

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued)

d. A nominal 10.4 inch center to center distance between fuel assemblies placed in Regions 1A and 1B; and

e. A nominal 9.125 inch center to center distance between fuel assemblies placed in Regions 2A and 2B.

4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum nominal U-235 enrichment of 4.75 weight percent;

b. keo 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the UFSAR;

c. ket 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in Section 9.1 of the UFSAR; and

d. A nominal 21 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 745 f!.-7 in.

4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 1463 fuel assemblies (286 total spaces in Regions 1A and 1B and 1177 total spaces in Regions 2A and 2B).

McGuire Units 1 and 2 4.0-2 Amendment Nos. 197/178

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Station Manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

5.1.2 The Shift Supervisor (SS) shall be responsible for the control room command function. During any absence of the SS from the control room while the unit is in MODE 1, 2, 3, or 4, an individual (other than the Shift Work Manager) with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the SS from the control room while the unit is in MODE 5 or 6, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

On occasion when there is a need for both the Shift Supervisor and the SRO to be absent from the control room in MODE 1, 2, 3, or 4, the Shift Work Manager shall be allowed to assume the control room command function and serve as the SRO in the control room provided that:

a. the Shift Supervisor is available to return to the control room within 10 minutes,

b. the assumption of SRO duties by the Shift Work Manager is limited to periods not in excess of 15 minutes duration and a total time not to exceed 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during any shift, and

c. the Shift Work Manager has a SRO license on the unit.

McGuire Units 1 and 2 5.1-1 Amendment Nos. 184/166

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements shall be documented in the UFSAR;

b. The Station Manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c. The Vice President of McGuire Nuclear Site shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety;

d. The Executive Vice President Nuclear Generation Department will be the Senior Nuclear Executive and have corporate responsibility for overall nuclear safety; and

e. The individuals who train the operating staff, carry out radiation protection, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

(continued)

McGuire Units 1 and 2 5.2-1 Amendment Nos. 184/166

Organization 5.2 5.2 Organization (continued) 5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned to each reactor containing fuel and an additional non-licensed operator shall be assigned for each control room from which a reactor is operating in MODES 1, 2, 3, or 4.

A total of three non-licensed operators are required for the two units.

b. At least one licensed Reactor Operator (RO) shall be present in the control room when fuel is in the reactor. In addition, while the unit is in MODE 1, 2, 3, or 4, at least one licensed Senior Reactor Operator (SRO) shall be present in the control room.

c. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.g for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

d. A Radiation Protection Technician shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

e. Administrative procedures shall be developed and implemented to limit the working hours of station staff who perform safety related functions (e.g., licensed SROs, licensed ROs, radiation protection technicians, auxiliary operators, and key maintenance personnel).

Adequate shift coverage shall be maintained without routine heavy use of overtime. The objective shall be to have operating personnel work a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months day with alternating 48 hour5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months and 36 hour4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months weeks while the unit is operating. However, in the event that unforeseen problems require substantial amounts of overtime to be used, or during extended periods of shutdown for refueling, major maintenance, or plant modification, on a temporary basis the following guidelines shall be followed:

1. An individual should not be permitted to work more than 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months straight, excluding shift turnover time; (continued)

McGuire Units and 2 5.2-2 Amendment Nos. 1841166

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

2. An individual should not be permitted to work more than 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months in any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period, nor more than 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months in any 48 hour5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months period, nor more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in any 7 day period, all excluding shift turnover time;

3. A break of at least 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months should be allowed between work periods, including shift turnover time;

4. Except during extended shutdown periods, the use of overtime should be considered on an individual basis and not for the entire staff on a shift.

Any deviation from the above guidelines shall be authorized in advance by the Station Manager or his designee, in accordance with approved administrative procedures, or by higher levels of management, in accordance with established procedures and with documentation of the basis for granting the deviation.

Controls shall be included in the procedures such that individual overtime shall be reviewed monthly by the Station Manager or his designee to ensure that excessive hours have not been assigned. Routine deviation from the above guidelines is not authorized.

f. The Operations Manager shall hold or have held an SRO license.

g. The Shift Work Manager, whose functions include those of a Shift Technical Advisor (STA), shall provide advisory technical support to the Shift Supervisor in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. In addition, the Shift Work Manager shall meet the qualifications for STA specified by the Commission Policy Statement on Engineering Expertise on Shift.

McGuire Units 1 and 2 5.2-3 Amendment Nos. 184/166

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI-N18.1-1 971 for comparable positions, except the Radiation Protection Manager, who shall meet or exceed the qualifications of Regulatory Guide 1.8, September 1975. The licensed Operators and Senior Reactor Operators shall also meet or exceed the minimum qualifications of the supplemental.

requirements specified in Sections A and C of Enclosure 1 of the March 28, 1980 NRC letter to all licensees.

McGuire Units 1 and 2 5.3-1 Amendment Nos. 184/166

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Commitments contained in UFSAR Chapter 16.0; and

e. All programs specified in Specification 5.5.

McGuire Units 1 and 2 5.4-1 Amendment Nos. 184/166

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, Implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program.

licensee initiated changes to the ODCM:

a. Shall be documented and records of reviews performed shall be retained.

This documentation shall contain:

1. sufficient Information to support the change(s) together with the appropriate analyses or evaluations ustifying the change(s), and

2. a determination that the change(s) do not adversely Impact the accuracy or reliability of effluent, dose, or setpoint calculations;

b. Shall become effective after the approval of the Station Manager; and

c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

5.5.2 Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, 'Performance-Based Containment Leak-Test Program," dated September 1995, as modified by the following exceptions:

a. NEI 94-01-1995, Section 9.2.3: The first Type A test performed after the May 27, 1993 (Unit 1) and August 20, 1993 (Unit 2) Type A test shall be performed no later than May 26, 2008 (Unit 1) and August 19, 2008 (Unit 2), and -

McGuire Units 1 and 2 5.5-1 Amendment Nos. 212/193

Programs and Manuals 5.5 5.5 Programs and Manuals (continued)

b. The containment visual examinations required by Regulatory Position C.3 shall be conducted 3 times every 10 years, including during each shutdown for SR 3.6.11 Type A test, prior to Initiating the Type A test.

5.5.2 Containment Leakage Rate Testinq Program (continued)

The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 14.8 psig. The containment design pressure is 15 psig.

The maximum allowable containment leakage rate, La, at Pa, shall be 0.3% of containment air weight per day.

Leakage Rate acceptance criteria are:

a. Containment leakage rate acceptance criterion is

1.0 La. During the first plant startup following testing in accordance with this program, the leakage rate acceptance criteria are c 0.75 L. for Type A tests and < 0.6 La for Type B and Type C tests.

b. Airlock testing acceptance criteria for the overall airlock leakage rate is

0.05 La when tested at Pa. For each door, the leakage rate is s 0.01 La when tested at 2 14.8 psig.

The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

Nothing n these Technical Specifications shall be construed to modify the testing frequencies required by 10CFR50, Appendix J.

5.5.3 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include Containment Spray, Safety Injection, Chemical and Volume Control, Nuclear Sampling, RHR, Boron Recycle, Refueling Water, Liquid Waste, and Waste Gas.

The program shall include the following:

a. Preventive maintenance and periodic visual nspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.4 Deleted McGuire Units and 2 5.5-2 Amendment Nos. 212/193

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.5 Radioactive Effluent Controls Proqram

a. 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 Chapter 16 of the UFSAR, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

1. 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;

2. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times 10 CFR 20, Part 20.1001 - 20.2401, Appendix B, Table 2, Column 2;

3. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1 302 and with the methodology and parameters in the ODCM;

4. 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 ;

5. 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;

6. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix ;

(continued)

McGuire Units 1 and 2 5.5-3 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.5 Radioactive Effluent Controls Program (continued)

7. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary shall be limited to the following:

i. For noble gases: Less than or equal to a dose rate of 500 mremlyr to the total body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and ii. For iodine-131, iodine-1 33, 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 mrem/yr to any organ;

8. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix ;

9. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-1 33, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix ;

10. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190; and

11. 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.

b. Licensee initiated changes to the Radiological Effluent Controls of the UFSAR:

1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

i. Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and (continued)

McGuire Units 1 and 2 5.5-4 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.5 Radioactive Effluent Controls Proqram (continued) ii. A determination that the change(s) maintain the overall conformance of the solidified waste product to existing requirements of Federal, State, or other applicable regulations or a determination that the change will maintain the level of radioactive effluent control required by 10 CFR 20.1302, 40 CFR Part 190, 10 CFR 50.36a, and Appendix I to 10 CFR Part 50 and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

2. Shall become effective after approval of the station manager.

3. Shall be submitted to the Commission in the form of a complete, legible copy of the entire Section 16.11 of the UFSAR as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any changes to Section 16.11 of the UFSAR was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e.,

month/year) the change was implemented.

5.5.6 Component Cyclic or Transient Limit This program provides controls to track the UFSAR, Section 5.2.1.5, cyclic and transient occurrences to ensure that components are maintained within the design limits.

5.5.7 Reactor Coolant Pump Flywheel Inspection ProQram 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 1, August 1975.

In lieu of Position C.4.b(1) and C.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle one-half of the outer radius or a surface examination (MT and/or PT) of exposed surfaces of the removed flywheels may be conducted at approximately 10 year intervals coinciding with the Inservice Inspection schedule as required by ASME Section Xl.

(continued)

McGuire Units 1 and 2 5.5-5 Amendment Jios. 190 (Unit 1')

171 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a. Testing frequencies specified in Section Xl of the ASME Boiler and Pressure Vessel Code and applicable Addenda as follows:

ASME Boiler and Pressure Vessel Code and applicable Required Frequencies for Addenda terminology for performing inservice testing inservice testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies for performing inservice testing activities;

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Tube Surveillance Program This program provides controls for the inservice inspection of steam generator tubes to ensure that the structural integrity of this portion of the RCS is maintained. The program for inservice inspection of steam generator tubes is based on a modification of Regulatory Guide 1.83, Revision 1. The program shall include:

(continued)

McGuire Units 1 and 2 5.5-6 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9.1 Steam Generator Sample Selection and Inspection Each steam generator shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum of steam generators specified in Table 5.5-1.

5.5.9.2 Steam Generator Tube Sample Selection and Inspection The steam generator tube minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5-2. The inservice inspection of steam generator tubes shall be performed at the frequencies specified in Specification 5.5.9.3 and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.9.4. The tubes selected for each inservice inspection shall include at least 3% of the total number of tubes in all steam generators; the tubes selected for these inspections shall be selected on a random basis except:

a. Where experience in similar plants with similar water chemistry indicates critical areas to be inspected, then at least 50% of the tubes inspected shall be from these critical areas;

b. The first sample of tubes selected for each inservice inspection (subsequent to the preservice inspection) of each steam generator shall include:

1. All nonplugged tubes that previously had detectable wall penetrations (greater than 20%),

2. Tubes in those areas where experience has indicated potential problems, and

3. A tube inspection (pursuant to Specification 5.5.9.4.a.8) shall be performed on each selected tube. If any selected tube does not permit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection.

c. The tubes selected as the second and third samples (if required by Table 5.5-2) during each inservice inspection may be subjected to a partial tube inspection provided:

1. The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfections were previously found, and (continued)

McGuire Units 1 and 2 5.5-7 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9.2 Steam Generator Tube Sample Selection and Inspection (continued)

2. The inspections include those portions of the tubes where imperfections were previously found.

The results of each sample inspection shall be classified into one of the following three categories:

Category Inspection Results C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective.

C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5%

and 10% of the total tubes inspected are degraded tubes.

C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.

Note: In all inspections, previously degraded tubes must exhibit significant (greater than 10%) further wall penetrations to be included in the above percentage calculations.

5.5.9.3 Inspection Frequencies The above required inservice inspections of steam generator tubes shall be performed at the following frequencies:

a. The first inservice inspection after the steam generator replacement shall be performed after at least 6 Effective Full Power Months but within 24 calendar months of initial criticality after steam generator replacement.

Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection. If two consecutive inspections following service under AVT conditions, not including the preservice inspection, result in all inspection results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months; (continued)

McGuire Units 1 and 2 5.5-8 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9.3 Inspection Frequencies (continued)

b. If the results of the inservice inspection of a steam generator conducted in accordance with Table 5.5-2 at 40-month intervals fall in Category C-3, the inspection frequency shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.9.3.a; the interval may then be extended to a maximum of once per 40 months; and

c. Additional, unscheduled inservice inspections shall be performed on each steam generator in accordance with the first sample inspection specified in Table 5.5-2 during the shutdown subsequent to any of the following conditions:

1. Reactor-to-secondary tubes leaks (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of Specification 3.4.13,

2. A seismic occurrence greater than the Operating Basis Earthquake,

3. A loss-of-coolant accident requiring actuation of the Engineered Safety Features, or

4. A main steam line or feedwater line break.

The provisions of SR 3.0.2 are applicable to the SG Tube Surveillance Program test frequencies.

5.5.9.4 Acceptance Criteria

a. As used in this specification:

1. Imperfection means an exception to the dimensions, finish or contour of a tube from that required by fabrication drawings or specifications. Eddy-current testing indications below 20% of the nominal tube wall thickness, if detectable, may be considered as imperfections;

2. Degradation means a service-induced cracking, wastage, wear or general corrosion occurring on either inside or outside of a tube; (continued)

McGuire Units 1 and 2 5.5-9 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9.4 Acceptance Criteria (continued)

3. Degraded Tube means a tube containing imperfections greater than or equal to 20% of the nominal tube wall thickness caused by degradation;

4. % degradation means the percentage of the tube wall thickness affected or removed by degradation;

5. Defect means an imperfection of such severity that it exceeds the plugging limit. A tube containing a defect is defective;

6. Plugging Limit means the imperfection depth at or beyond which the tube shall be removed from service by plugging. The plugging limit is equal to 40% of the nominal tube wall thickness.

7. Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break as specified in 5.5.9.3.c, above;

8. Tube Inspection means an inspection of the steam generator tube from the point of entry completely around the U-bend to the point of exit; and

9. Preservice Inspection means an inspection of the full length of each tube in each steam generator performed by eddy current techniques prior to service to establish a baseline condition of the tubing. This inspection shall be performed prior to initial POWER OPERATION using the equipment and techniques expected to be used during subsequent inservice inspections.

b. The steam generator shall be determined OPERABLE after completing the corresponding actions required by Table 5.5-2.

(continued)

McGuire Units 1 and 2 5.5-1 0 Amendment Nos. 184/166

Programs and Manuals 5.5 TABLE 5.5-1 (Page 1 of 1)

MINIMUM NUMBER OF STEAM GENERATORS TO BE INSPECTED DURING INSERVICE INSPECTION Preservice Inspection No Yes No. of Steam Generators per Unit Four Four First Inservice Inspection after the All Two Steam Generator Replacement Second & Subsequent Inservice One' One2 Inspections Table Notation

1. The inservice inspection may be limited to one steam generator on a rotating schedule encompassing 3 N % of the tubes (where N is the number of steam generators in the unit) if the results of the first or previous inspections indicate that all steam generators are performing in a like manner. Note that under some circumstances, the operating conditions in one or more steam generators may be found to be more severe than those in other steam generators. Under such circumstances the sample sequence shall be modified to inspect the most severe conditions.

2. Each of the other two steam generators not inspected during the first inservice inspections after the steam generator replacement shall be inspected during the second and third inspections. The fourth and subsequent inspections shall follow the instructions described in 1 above.

McGuire Units 1 and 2 5.5-1 1 Amendment Nos. 184/166

Programs and Manuals 5.5 TABLE 5.5-2 STEAM GENERATOR TUBE INSPECTION 1ST SAMPLE INSPECTION 2ND SAMPLE INSPECTION 3RD SAMPLE INSPECTION Sample Size Result Action Result Action Required Result Action Required

.. I Required I I A minimum C-1 None NIA N/A NIA NIA of S tubes per SG

4. 4. 4 C-2 Plug C-1 None N/A N/A defective tubes and inspect additional 2S tubes in this SG C-2 Plug defective C-1 None tubes and inspect additional 4S tubes in this SG C-2 Plug defective tubes C-3 Perform action for C-3 result of first sample C-3 Perform action for N/A N/A 0-3 result of first sample C-3 Inspect all All other None N/A N/A tubes in this SGs are C-1 SG, plug defective tubes and inspect 2S tubes in each other SG Some SGs Perform action for N/A N/A C-2 but no C-2 result of additional second sample SGs are 0-3 Additional Inspect all tubes N/A N/A SG is C-3 in each SG and plug defective tubes.

S = 3N/n % Where N is the number of steam generators in the unit, and n is the number of steam generators inspected during an inspection.

McGuire Units 1 and 2 5.5-1 2 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.10 Secondary Water Chemistry Program This 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:

a. Identification of a sampling schedule for the critical variables and control points for these variables;

b. Identification of the procedures used to measure the values of the critical variables;

c. Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage;

d. Procedures for the recording and management of data;

e. Procedures defining corrective actions for all off control point chemistry conditions; and

f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

5.5.11 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975, with exceptions as noted in the UFSAR.

a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows the following penetration and system bypass when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 (N510-1980 for Auxiliary Building Filtered Exhaust) at the flowrate specified below t 10%.

(continued)_

McGuire Units 1 and 2 5.5-1 3 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation Filter Testinq Program (VFTP) (continued)

ESF Ventilation System Penetration Flowrate Annulus Ventilation <1% 8000 cfm Control Area Ventilation < 0.05% 2000 cfm Aux. Bldg. Filtered Exhaust (2 fans)(Unit 1) <1% 45,700 cfm Aux. Bldg. Filtered Exhaust (2 fans)(Unit 2) <1% 40,500 cfm Containment Purge (non-ESF) (2 fans) <1% 21,000 cfm Fuel Bldg. Ventilation (non-ESF) <1% 35,000 cfm

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows the following penetration and system bypass when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 (N510-1980 for Auxiliary Building Filtered Exhaust) at the flowrate specified below +/- 10%.

ESF Ventilation System Penetration Flowrate Annulus Ventilation <1% 8000 cfm Control Area Ventilation < 0.05% 2000 cfm Aux. Bldg. Filtered Exhaust (2 fans)(Unit 1) <1% 45,700 cfm Aux. Bldg. Filtered Exhaust (2 fans)(Unit 2) <1% 40,500 cfm Containment Purge (non-ESF) (2 fans) <1% 21,000 cfm Fuel Bldg. Ventilation (non-ESF) <1% 35,000 cfm

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at the temperature and relative humidity (RH) specified below.

ESF Ventilation System Penetration RH Temp.

Annulus Ventilation <4% 95% 300 C Control Area Ventilation < 0.95% 95% 300 C Aux. Bldg. Filtered Exhaust <4% 95% 300 C Containment Purge (non-ESF) <4% 95% 300 C Fuel Bldg. Ventilation (non-ESF) <4% 95% 300C

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 at the flowrate specified below+/- 10%.

(continued)

McGuire Units and 2 5.5-14 Amendment Nos. 196/177

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation System Delta P Flowrate Annulus Ventilation 6.0 in wg 8000 cfm Control Area Ventilation 5.0 in wg 2000 cfm Aux. Bldg. Filtered Exhaust (2 fans)(Unit 1) 6.0 in wg 45,700 cfm Aux. Bldg. Filtered Exhaust (2 fans)(Unit 2) 6.0 in wg 40,500 cfm Containment Purge (non-ESF) (2 fans) 6.0 in wg 21,000 cfm Fuel Bldg. Ventilation (non-ESF) 6.0 in wg 35,000 cfm

e. Demonstrate that the heaters for each of the ESF systems dissipate the value specified below when tested in accordance with ANSI N510-1975.

ESF Ventilation System Wattage @ 600 VAC Annulus Ventilation 43.0 + 6.4 kW Control Area Ventilation 10.0 + 1.0 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 controls for potentially explosive gas mixtures contained in the Waste Gas Holdup System, the quantity of radioactivity contained in gas storage tanks or fed into the off gas treatment system, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks. The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, Postulated Radioactive Release due to Waste Gas System Leak or Failure". The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3,

'Postulated Radioactive Release due to Tank Failures'.

The program shall include:

a. The limits for concentrations of hydrogen and oxygen in the Waste Gas Holdup System and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion);

(continued)

McGuire Units 1 and 2 5.5-1 5 Amendment Nos. 184/166

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

b. A surveillance program to ensure that the quantity of radioactivity contained in each gas storage tank or connected gas storage tanks and fed into the offgas treatment system is less than the amount that would result in a Deep Dose Equivalent of > 0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and C. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is less than the amount that would result in concentrations exceeding the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

5.5.13 Diesel Fuel Oil Testina Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1. an API gravity or an absolute specific gravity within limits,

2. a flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3. a clear and bright appearance with proper color or a water and sediment content within limits;

b. Other properties for ASTM 2D fuel oil are within limits within 31 days following sampling and addition to storage tanks; and (continued)

McGuire Units 1 and 2 5.5-1 6 Amendment Nos. 215 & 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Diesel Fuel Oil Testing Program (continued)

c. Total particulate concentration of the fuel oil is

10 mg/l when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test frequencies.

5.5.14 Technical Specifications (TS) Bases Control Proaram This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. A change in the'TS incorporated in the license; or

2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50. 59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the UFSAR.

d. Proposed changes that meet the criteria of Specification 5.5.14.b.1 or 5.5.14.b.2 above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71 (e).

5.5.15 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

(continued)

McGuire Units I and 2 5.5-1 7 Amendment Nos. 215 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Safety Function Determination Program (SFDP) (continued)

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or

b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or

c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

McGuire Units and 2 5.5-1 8 Amendment Nos. 184/166

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Occupational Radiation Exposure Report A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

A tabulation on an annual basis of the number of station, utility, and other personnel (including contractors) for whom monitoring was performed, receiving an annual deep dose equivalent > 100 mrems and the associated collective deep dose equivalent (reported in person-rem) according to work and job functions (e.g., reactor operations and surveillance, inservice inspection, routine maintenance, special maintenance (describe maintenance), waste processing, and refueling). This tabulation supplements the requirements of 10 CFR 20.2206. The dose assignments to various duty functions may be estimated based on pocket ionization chamber, electronic dosimetry, thermoluminescent dosimeter (TLD), or film badge measurements. Small exposures totalling < 20% of the individual total dose need not be accounted for.

In the aggregate, at least 80% of the total deep dose equivalent received from external sources should be assigned to specific major work functions. The report covering the previous calendar year shall be submitted by April 30 of each year.

5.6.2 Annual Radiological Environmental Operating Report

-- D--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 Chapter 16 of the UFSAR and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

(continued)

McGuire Units 1 and 2 5.6-1 Amendment Nos. 184/166

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radiological Environmental Operating Report (continued)

The Annual Radiological Environmental Operating Report shall include summarized and tabulated results of the 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 common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

The Radioactive Effluent Release Report covering the operation of the unit in the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit.

The material provided shall be consistent with the objectives outlined in Chapter 16 of the UFSAR and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.

5.6.4 Monthly Operating Reports Routine reports of operating statistics and shutdown experience, including documentation of all challenges to the pressurizer power operated relief valves or pressurizer safety valves, shall be submitted on a monthly basis no later than the 15th of each month following the calendar month covered by the report.

5.6.5 CORE OPERATING LIMITS REPORT (COLRI

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1. Moderator Temperature Coefficient BOL and EOL limits and 60 ppm and 300 ppm surveillance limits for Specification 3.1.3, (continued)

McGuire Units 1 and 2 5.6.2 Amendment Nos. 208 & 189

5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

2. Shutdown Bank Insertion Limit for Specification 3.1.5,

3. Control Bank Insertion Limits for Specification 3.1.6,

4. Axial Flux Difference limits for Specification 3.2.3,

5. Heat Flux Hot Channel Factor for Specification 3.2.1,

6. Nuclear Enthalpy Rise Hot Channel Factor limits for Specification 3.2.2,

7. Overtemperature and Overpower Delta T setpoint parameter values for Specification 3.3.1,

8. Accumulator and Refueling Water Storage Tank boron concentration limits for Specification 3.5.1 and 3.5.4,

9. Reactor Coolant System and refueling canal boron concentration limits for Specification 3.9.1,

10. Spent fuel pool boron concentration limits for Specification 3.7.14,

11. SHUTDOWN MARGIN for Specification 3.1.1, and

12. 31 EFPD Surveillance Penalty Factors for Specifications 3.2.1 and 3.2.2.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. WCAP-9272-P-A, WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," Proprietary).

2. WCAP-1 0266-P-A, THE 1981 VERSION OF WESTINGHOUSE EVALUATION MODEL USING BASH CODE," (W Proprietary).

3. BAW-1 01 68P-A, B&W Loss-of-Coolant Accident Evaluation Model for Recirculating Steam Generator Plants,' (B&W Proprietary).

(continued)

McGuire Units 1 and 2 5.6-3 Amendment tlos. 208 & 189

5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

4. DPC-NE-2011 PA, "Duke Power Company Nuclear Design Methodology for Core Operating Limits of Westinghouse Reactors," (DPC Proprietary).

5. DPC-NE-3001PA, Multidimensional Reactor Transients and Safety Analysis Physics Parameter Methodology," (DPC Proprietary).

6. DPC-NF-2010A, "Duke Power Company McGuire Nuclear Station Catawba Nuclear Station Nuclear Physics Methodology for Reload Design".

7. DPC-NE-3002A, "FSAR Chapter 15 System Transient Analysis Methodology". I

8. DPC-NE-3000PA, "Thermal-Hydraulic Transient Analysis Methodology," (DPC Proprietary).

9. DPC-NE-1004A, "Nuclear Design Methodology Using CASMO-3/SIMULATE-3P". I

10. DPC-NE-2004P-A, "Duke Power Company McGuire and Catawba l Nuclear Stations Core Thermal-Hydraulic Methodology using VIPRE-Ol," (DPC Proprietary). I

11. DPC-NE-2005P-A, "Thermal Hydraulic Statistical Core Design Methodology," (DPC Proprietary).

12. DPC-NE-2008P-A, "Fuel Mechanical Reload Analysis Methodology Using TACO3," (DPC Proprietary). l

13. WCAP-1 0054-P-A, "Westinghouse Small Break ECCS Evaluation Model using the NOTRUMP Code," & Proprietary). l

14. DPC-NE-2009-P-A, "Westinghouse Fuel Transition Report," (DPC l Proprietary).

15. WCAP-12945-P-A, Volume 1 and Volumes 2-5, "Code l Qualification Document for Best-Estimate Loss of Coolant Analysis," CW. Proprietary).

The COLR will contain the complete identification for each of the Technical Specifications referenced topical reports used to prepare the COLR (i.e., report number, title, revision number, report date or NRC SER date, and any supplements).

(continued)

McGuire Units 1 and 2 5.6-4 Amendment Nos. 203/184

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

5.6.6 Ventilation Systems Heater Failure Report When a report is required by LCOs 3.6.10, Annulus Ventilation System (AVS),"

or LCO 3.7.9, "Control Room Area Ventilation System (CRAVS)," a report shall be submitted within the following 30 days. The report shall outline the reason for the inoperability and the planned actions to return the systems to OPERABLE status.

5.6.7 PAM Report When a report is required by LCO 3.3.3, "Post Accident Monitoring (PAM)

Instrumentation,' a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.8 Steam Generator Tube Inspection Report

a. The number of tubes plugged in each steam generator shall be reported to the NRC within 15 days following completion of the program;

b. The complete results of the Steam Generator Tube Surveillance Program shall be reported to the NRC within 12 months following the completion of the program and shall include:

1. Number and extent of tubes inspected,

2. Location and percent of wall-thickness penetration for each indication of an imperfection, and

3. Identification of tubes plugged.

(continued)

McGuire Units 1 and 2 5.6-5 Amendment Nos. 184/166

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.1 Pursuant to 10 CFR 20, paragraph 20.1601 (c), in lieu of the requirements of 10 CFR 20.1601, each high radiation area, as defined in 10 CFR 20, in which the intensity of radiation is > 100 mrem/hr but < 1000 mrem/hr at 30 cm (12 in.) from the radiation source or from any surface which the radiation penetrates, shall be barricaded and conspicuously posted as a high radiation area and entrance thereto shall be controlled by requiring issuance of a Radiation Work Permit (RWP). Individuals qualified in radiation protection procedures (e.g., Radiation Protection Technicians) or personnel continuously escorted by such individuals may be exempt from the RWP 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 following:

a. A radiation monitoring device that continuously indicates the radiation dose rate in the area.

b. 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.

c. 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 Manager in the RWP.

5.7.2 In addition to the requirements of Specification 5.7.1, areas with radiation levels

> 1000 mrem/hr at 30 cm (12 in.) from the radiation source or from any surface which the radiation penetrates 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 Supervisor on duty or radiation protection personnel. Doors shall remain locked except during periods of access by personnel under an approved RWP that shall specify the dose rate levels in the immediate work areas and the maximum allowable stay times for individuals in those areas. In lieu of the stay time specification of the RWP, direct or remote (such as closed circuit TV cameras) continuous surveillance may be made by personnel qualified in radiation protection procedures to provide positive exposure control over the activities being performed within the area.

(continued)

McGuire Units 1 and 2 5.7-1 Amendment Nos. 184/166

High Radiation Area 5.7 5.7 High Radiation Area 5.7.3 For individual high radiation areas with radiation levels of > 1000 mrem/hr at 30 cm (12 in.), accessible to personnel, that are located within large areas such as reactor containment, where no enclosure exists for purposes of locking, or that cannot be continuously guarded, 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.

McGuire Units 1 and 2 5.7-2 Amendment Nos. 184/166

APPENDIX B ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-9 Duke Energy Corporation shall comply with the following conditions on the schedules noted below:

Amendment Implementation Number Additional Date Conditions 184 The schedule for the performance of new and Within 90 days of the revised surveillance requirements shall be as date of this follows: amendment.

For surveillance requirements (SRs) that are new in Amendment No. 184 the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment No. 184. For SRs that existing prior to Amendment No. 184, including SRs with modified acceptance criteria and SRs whose intervals of performance are being extended, the first performance is due at the end of the first surveillance interval that begins on the date the surveillance was last performed prior to implementation of amendment No. 184. For SRs that existed prior to Amendment No. 184, whose intervals of performance are being reduced, the first reduced surveillance interval begins upon completion of the first surveillance performed after implementation of Amendment No. 184.

188 The maximum rod average burnup for any rod Within 30 days of shall be limited to 60 GWd/mtU until the date of this completion of an NRC environmental amendment assessment supporting an increased limit. _

Amendment No. 200 APPENDIX C ANTITRUST CONDITIONS Pursuant to an Order by the Atomic Safety and Licensing Board, dated April 23, 1975, the Nuclear Regulatory Commission incorporates in Renewed Operating License NPF-9 the following antitrust conditions:

a. The licensee makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants such arrangements also serve the best interests of each of the participants.'

Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.

Any particular bulk power supply transaction may afford greater benefits to one participant than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, the licensee will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to the licensee. There are net benefits in a transaction if the licensee recovers the cost of the transaction, (as defined in subparagraph (1)(d) hereof) and there is no demonstrable net detriment to the licensee arising from the transaction.

(1) As used herein:

(a) 'Bulk Power" means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.

(b) 'Neighboring Entity" means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of the following criteria: (1) its existing or proposed facilities are economically and technically feasible of interconnection with those of the licensee and (2) with the exception of municipalities, cooperatives, governmental agencies or authorities, and associations, it is, or upon commencement of operations will be, a public utility and subject to regulation with respect to rates and service under the laws of North Carolina or South Carolina or under the Federal Power Act; provided, however, that as to associations, each member of such association is either a public utility as discussed in this clause (2) or a municipality, a cooperative or a governmental agency or authority.

Amendment No. 200 c-l

(c) Where the phrase "neighboring entity" is intended to include entities engaging or proposing to engage only in the distribution of electricity, this is indicated by adding the phrase "including distribution systems."

(d) 'Cost" means any appropriate operating and maintenance expenses, together with all other costs, including a reasonable return on the licensee's investment, which are reasonably allocable to a transaction.

However, no value shall be included for loss of revenue due to the loss of any wholesale or retail customer as a result of any transaction hereafter described.

(2) (a) The licensee will interconnect and coordinate reserves by means of the sale and exchange of emergency and scheduled maintenance bulk power with any neighboring entity(ies), when there are net benefits to each party, on terms that will provide for all of the licensee's properly assignable costs as may be determined by the Federal Energy Regulatory Commission and consistent with such cost assignment will allow the other party the fullest possible benefits of such coordination.

(b) Emergency service and/or scheduled maintenance service to be provided by each party will be furnished to the fullest extent available from the supplying party and desired by the party in need. The licensee and each party will provide to the other emergency service and/or scheduled maintenance service if and when available from its own generation and, in accordance with recognized industry practice, from generation of others to the extent it can do so without impairing service to its customers, including other electric systems to whom it has firm commitments.

(c) Each party to a reserve coordination arrangement will establish its own reserve criteria, but in no event shall the minimum installed reserve on each system be less than 15%, calculated as a percentage of estimated peak load responsibility. Either party, if it has, or has firmly planned, installed reserves in excess of the amount called for by its own reserve criterion, will offer any such excess as may in fact be available at the time for which it is sought and for such period as the selling party shall determine for purchase in accordance with reasonable industry practice by the other party to meet such other party's own reserve requirements.

The parties will provide such amounts of spinning reserve as may be adequate to avoid the imposition of unreasonable demands on the other part(ies) in meeting the normal contingencies of operating its (their) system(s). However, in no circumstances shall such spinning reserve requirement exceed the installed reserve requirement.

Amendment No. 200 C-2

(d) Interconnections will not be limited to low voltages when higher voltages are available from the licensee's installed facilities in the area where interconnection is desired and when the proposed arrangement is found to be technically and economically feasible.

(e) Interconnection and reserve coordination agreements will not embody provisions which impose limitations upon the use or resale of power and energy sold or exchanged pursuant to the agreement. Further, such arrangements will not prohibit the participants from entering into other interconnection and coordination arrangements, but may include appropriate provisions to assure that (i) the licensee receives adequate notice of such additional interconnection or coordination, (ii) the parties will jointly consider and agree upon such measures, if any, as are reasonably necessary to protect the reliability of the interconnected systems and to prevent undue burdens from being imposed on any system, and (iii) the licensee will be fully compensated for its costs.

Reasonable industry practice as developed in the area from time to time will satisfy this provision.

(3) The licensee currently has on file, and may hereafter file, with the Federal Energy Regulatory Commission contracts with neighboring entity(ies) providing for the sale and exchange of short-term power and energy, limited term power and energy, economy energy, non-displacement energy, and emergency capacity and energy. The Licensee will enter into contracts providing for the same or for like transactions with any neighboring entity on terms which enable the licensee to recover the full costs allocable to such transaction.

(4) The licensee currently sells capacity and energy in bulk on a full requirements basis to several entities engaging in the distribution of electric power at retail. In addition, the licensee supplies electricity directly to ultimate users in a number of municipalities. Should any such entity(ies) or municipality(ies) desire to become a neighboring entity as defined in subparagraph (1)(b) hereof (either alone or through combination with others), the licensee will assist in facilitating the necessary transition through the sale of partial requirements firm power and energy to the extent that, except for such transition, the licensee would otherwise be supplying firm power and energy. The provision of such firm partial requirements service shall be under such rates, terms and conditions as shall be found by the Federal Energy Regulatory Commission to provide for the recovery of the licensee's cost. The licensee will sell capacity and energy in bulk on a full requirements basis to any municipality currently served by the licensee when such municipality lawfully engages in the distribution of electric power at retail.

(5) (a) The licensee will facilitate the exchange of electric power in bulk in wholesale transactions over its transmission facilities (1) between or Amendment No. 200 C-3

among two or more neighboring entities including distribution systems with which it is interconnected or may be interconnected in the future, and (2) between any such entity~ies) and any other electric system engaging in bulk power supply between whose facilities the licensee's transmission lines and other transmission lines would form a continuous electric path, provided that permission to utilize such other transmission lines has been obtained. Such transaction shall be undertaken provided that the particular transaction reasonably can be accommodated by the licensee's transmission system from a functional and technical standpoint and does not constitute the wheeling of power to a retail customer. Such transmission shall be on terms that fully compensate the licensee for its cost. Any entity(ies) requesting such transmission arrangements shall give reasonable notice of its (their) schedule and requirements.

(b) The licensee will include in its planning and construction program sufficient transmission capacity as required for the transactions referred to in subparagraph (a)of this paragraph, provided that (1) the neighboring entity(ies) gives the licensee sufficient advance notice as may be necessary reasonably to accommodate its (their) requirements from a functional and technical standpoint and (2) that such entity(ies) fully compensate the licensee for its cost. In carrying out this subparagraph (b), however, the licensee shall not be required to construct or add transmission facilities which (a)will be of no demonstrable present or future benefit to the licensee, or (b)which could be constructed by the requesting entity(ies) without duplicating any portion of the licensee's existing transmission lines, or (c) which would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.

Where regulatory or environmental approvals are required for the construction or addition of transmission facilities needed for the transactions referred to in subparagraph (a) of this paragraph it shall be the responsibility of the entity~ies) seeking the transaction to participate in obtaining such approvals, including sharing in the cost thereof.

(6) To increase the possibility of achieving greater reliability and economy of electric generation and transmission facilities, the licensee will discuss load projections and system development plans with any neighboring entity(ies).

(7) When the licensee's plans for future nuclear generating units (for which application will hereafter be made to the Nuclear Regulatory Commission) have reached the stage of serious planning, but before firm decisions have been made as to the size and desired completion date of the proposed nuclear units, the licensee will notify all neighboring entities including distribution systems with peak loads smaller than the licensee's that the licensee plans to construct such Amendment No. 200 CA

nuclear units. Neither the timing nor the information provided need be such as to jeopardize obtaining the required site at the lowest possible cost.

(8) The foregoing commitments shall be implemented in a manner consistent with the provisions of the Federal Power Act and all other lawful local, state and Federal regulation and authority. Nothing in these commitments is intended to determine in advance the resolution of issues which are properly raised at the Federal Energy Regulatory Commission concerning such commitments, including allocation of costs or the rates to be charged. The licensee will negotiate (including the execution of a contingent statement of intent) with respect to the foregoing commitments with any neighboring entity including distribution systems where applicable engaging in or proposing to engage in bulk power supply transactions, but the licensee shall not be required to enter into any final arrangement prior to resolution of any substantial questions as to the lawful authority of an entity to engage in the transactions.

In addition, the licensee shall not be obligated to enter into a given bulk power supply transaction if: (1)to do so would violate, or incapacitate it from performing, any existing lawful contracts it has with a third party; (2) there is contemporaneously available to it a competing or alternative arrangement which affords it greater benefits which would be mutually exclusive of such arrangement; (3)to do would adversely affect its system operations or the reliability of power supply to its customers, or (4) if to do so would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.

Amendment No. 200 C-5

APPENDIX B ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-17 Duke Energy Corporation shall comply with the following conditions on the schedules noted below:

Amendment Number Additional Implementation Conditions Date 166 The schedule for the performance of new and revised Within 90 days of the surveillance requirements shall be as follows: date of this amendment.

For surveillance requirements (SRs) that are new in Amendment No. 166 the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment No. 166. For SRs that existing prior to Amendment No. 166, including SRs with modified acceptance criteria and SRs whose intervals of performance are being extended, the first performance is due at the end of the first surveillance interval that begins on the date the surveillance was last performed prior to implementation of Amendment No. 166. For SRs that existed prior to Amendment No. 166, whose intervals of performance are being reduced, the first reduced surveillance interval begins upon completion of the first surveillance performed after implementation of Amendment No. 166.

169 The maximum rod average burnup for any rod shall Within 30 days of be limited to 60 GWd/mtU until the completion of an date of amendment NRC environmental assessment supporting an increased limit. _

Amendment 181 APPENDIX C ANTITRUST CONDITIONS Pursuant to an Order by the Atomic Safety and Licensing Board, dated April 23, 1975, the Nuclear Regulatory Commission incorporates in Operating License NPF-17 the following antitrust conditions:

a. The licensee makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants such arrangements also serve the best interests of each of the participants.

Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.

Any particular bulk power supply transaction may afford greater benefits to one particular than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, the licensee will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to the licensee. There are net benefits in a transaction if the licensee recovers the cost of the transaction (as defined in subparagraph (1)(d) hereof) and there is no demonstrable net detriment to the licensee arising from the transaction.

(1) As used herein:

(a) "Bulk Power" means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.

(b) "Neighboring Entity' means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of the following criteria:

(1) its existing or proposed facilities are economically and technically feasible of interconnection with those of the licensee and (2) with the exception of municipalities, cooperatives, governmental agencies or authorities, and associations, it is, or upon commencement of operations will be, a public utility and subject to regulation with respect to rates and service under the laws of North Carolina or South Carolina or under the Federal Power Act; provided, however, that as to associations, each member of such association is either a public utility as discussed in this clause (2) or Amenement 181 C-l

a municipality, a cooperative or a governmental agency or authority.

(c) Where the phrase neighboring entity" is intended to include entities engaging or proposing to engage only in the distribution of electricity, this is indicated by adding the phrase including distribution systems."

(d) NCost means any appropriate operating and maintenance expenses, together with all other costs, including a reasonable return on the licensee's investment, which are reasonably allocable to a transaction.

However, no value shall be included for loss of revenues due to the loss of any wholesale or retail customer as a result of any transaction hereafter described.

(2) (a) The licensee will interconnect and coordinate reserves by means of the sale and exchange of emergency and scheduled maintenance bulk power with any neighboring entity(ies), when there are net benefits to each party, on terms that will provide for all of the licensee's properly assignable costs as may be determined by the Federal Energy Regulatory Commission and consistent with such cost assignment will allow the other party the fullest possible benefits of such coordination.

(b) Emergency service and/or scheduled maintenance service to be provided by each party will be furnished to the fullest extent available from the supplying party and desired by the party in need. The licensee and each party will provide to the other emergency service and/or scheduled maintenance service if and when available from its own generation and, in accordance with recognized industry practice, from generation of others to the extent it can do so without impairing service to its customers, including other electric systems to whom it has firm commitments.

(c) Each party to a reserve coordination arrangement will establish its own reserve criteria, but in no event shall the minimum installed reserve on each system be less than 15%, calculated as a percentage of estimated peak load responsibility. Either party, if it has, or has firmly planned, installed reserves in excess of the amount called for by its own reserve criterion, will offer any such excess as may in fact be available at the time for which it is sought and for such period as the selling party shall determine for purchase in accordance with reasonable industry practice by the other party to meet such other party's own reserve requirements.

The parties will provide such amounts of spinning reserve as may be adequate to avoid the imposition of unreasonable demands on the other part(ies) in meeting the normal contingencies of operating its (their) system(s). However, in no circumstances shall such spinning reserve requirement exceed the installed reserve requirement.

(d) Interconnections will be limited to low voltages when higher voltages are Amenement 181 C-2

available from the licensee's installed facilities in the area where interconnection is desired and when the proposed arrangement is found to be technically and economically feasible.

(e) Interconnection and reserve coordination agreements will not embody provisions which impose limitations upon the use or resale of power and energy sold or exchanged pursuant to the agreement. Further, such arrangements will not prohibit the participants from entering into other interconnection and coordination arrangements, but may include appropriate provisions to assure that (i) the licensee receives adequate notice of such additional interconnection or coordination, (ii) the parties will jointly consider and agree upon such measures, if any, as are reasonably necessary to protect the reliability of the interconnected systems and to prevent undue burdens from being imposed on any system, and (iii) the licensee will be fully compensated for its costs.

Reasonable industry practice as developed in the area from time to time will satisfy this provision.

(3) The licensee currently has on file, and may hereafter file, with the Federal Energy Regulatory Commission contracts with neighboring entity(ies) providing for the sale and exchange of short-term power and energy, limited term power and energy, economy energy, non- displacement energy, and emergency capacity and energy. The licensee will enter into contracts providing for the same or for like transactions with any neighboring entity on terms which enable the licensee to recover the full costs allocable to such transaction.

(4) The licensee currently sells capacity and energy in bulk on a full requirements basis to several entities engaging in the distribution of electric power at retail. In addition, the licensee supplies electricity directly to ultimate users in a number of municipalities. Should any such entity(ies) or municipality(ies) desire to become a neighboring entity as defined in subparagraph (1)(b) hereof (either alone or through combination with others), the licensee will assist in facilitating the necessary transition through the sale of partial requirements firm power and energy to the extent that, except for such transition, the licensee would otherwise be supplying firm power and energy. The provision of such firm partial requirements service shall be under such rates, terms and conditions as shall be found by the Federal Energy Regulatory Commission to provide for the recovery of the licensee's cost. The licensee will sell capacity and energy in bulk on a full requirements basis to any municipality currently served by the licensee when such municipality lawfully engages in the distribution of electric power at retail.

(5) (a) The licensee will facilitate the exchange of electric power in bulk in wholesale transactions over its transmission facilities (1) between or among two or more neighboring entities including distribution systems with which it is interconnected or may be interconnected in the future, and (2) between any such entity(ies) and any other electric system engaging in bulk power supply between whose facilities the licensee's transmission Amenement 181 C-3

lines and other transmission lines would form a continuous electric path, provided that permission to utilize such other transmission lines has been obtairied. Such transaction shall be undertaken provided that the particular transaction reasonably can be accommodated by the licensee's transmission system from a functional and technical standpoint and does not constitute the wheeling of power to a retail customer. Such transmission shall be on terms that fully compensate the licensee for its cost. An entity(ies) requesting such transmission arrangements shall give reasonable notice of its (their) schedule and requirements.

(b) The licensee will include in its planning and construction program sufficient transmission capacity as required for the transactions referred to in subparagraph (a) of this paragraph, provided that (1) the neighboring entity(ies) gives the licensee sufficient advance notice as may be necessary reasonably to accommodate its (their) requirements from a functional and technical standpoint and (2) that such entity(ies) fully compensate the licensee for its cost. In carrying out this subparagraph (b), however, the licensee shall not be required to construct or add transmission facilities which (a) will be of no demonstrable present or future benefit to the licensee, or (b) which could be constructed by the requesting entity(ies) without duplicating any portion of the licensee's existing transmission lines, or (c) which would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.

Where regulatory or environmental approvals are required for the construction or addition of transmission facilities needed for the transactions referred to in subparagraph (a) of this paragraph it shall be the responsibility of the entity(ies) seeking the transaction to participate in obtaining such approvals, including sharing in the cost thereof.

(6) To increase the possibility of achieving greater reliability and economy of electric generation and transmission facilities, the licensee will discuss load projections and system development plans with any neighboring entity(ies).

(7) When the licensee's plans for future nuclear generating units (for which application will hereafter be made to the Nuclear Regulatory Commission) have reached the stage of serious planning, but before firm decisions have been made as to the size and desired completion date of the proposed nuclear units, the licensee will notify all neighboring entities including distribution systems with peak loads smaller than the licensee's that the licensee plans to construct such nuclear units. Neither the timing nor the information provided need be such as to jeopardize obtaining the required site at the lowest possible cost.

The foregoing commitments shall be implemented in a manner consistent with the provisions of the Federal Power Act and all other lawful local, state and Federal regulation and authority. Nothing in these commitments is intended to determine in advance the resolution of issues which are properly raised at the Federal Energy Regulatory Commission concerning such commitments, Amenement 181 C-4

including allocation of costs or the rates to be charged. The licensee will negotiate (including the execution of a contingent statement of intent) with respect to the foregoing commitments with any neighboring entity including distribution systems where applicable engaging in or proposing to engage in bulk power supply transactions, but the licensee shall not be required to enter into any final arrangement prior to resolution of any substantial questions as to the lawful authority of an entity to engage in the transactions.

In addition, the licensee shall not be obligated to enter into a given bulk power supply transaction if: (1) to do so would violate, or incapacitate it from performing, any existing lawful contracts it has with a third party; (2) there is contemporaneously available to it a competing or alternative arrangement which affords it greater benefits which would be mutually exclusive of such arrangement; (3) to do so would adversely affect its system operations or the reliability of power supply to its customers, or (4) if to do so would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.

Amenement 181 C-5

ML033070046

Text

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