ML18058B830

Updated Proposed Tech Specs Pages Re Shutdown Cooling

ML18058B830
Person / Time
Site:	Palisades
Issue date:	05/19/1993
From:	CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
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ML18058B829	List: ML18058B827 ML18058B830
References
NUDOCS 9305260045
Download: ML18058B830 (21)

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ATTACHMENT 1 Consumers Power Company Palisades Plant Docket 50-255 SHUTDOWN COOLING TECHNICAL SPECIFICATIONS CHANGE REQUEST Updated Proposed Pages May 19, 1993 20 Pages

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. 9305260045 930519 ---- ~ ~.

~DR* ADDCK 0500025 5 PDR

P~SADES PLANT TECHNICAL SPECIFIC~ONS TABLE OF CONTENTS SECTION DESCRIPTION PAGE NO I.O DEFINITIONS I-I I.I REACTOR OPERATING CONDITIONS I-I I.2 PROTECTIVE SYSTEMS I-3 I.3 INSTRUMENTATION SURVEILLANCE I-3 I.4 MISCELLANEOUS DEFINITIONS I-4 2.0 SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS 2-I 2.I SAFETY LIMITS - REACTOR CORE 2-I 2.2 SAFETY LIMITS - PRIMARY COOLANT SYSTEM PRESSURE 2-I 2.3 LIMITING SAFETY SYSTEM SETTINGS - RPS 2-I Table 2.3.I Reactor Protective System Trip Setting Limits 2-2 B2.I Basis - Reactor Core Safety Limit B2-I B2.2 Basis - Primary Coolant System Safety Limit B2-2 B2.3 Basis - Limiting Safety System Settings B2-3 3.0 LIMITING CONDITIONS FOR OPERATION 3-I 3.0 APPLICABILITY 3-I

3. I PRIMARY COOLANT SYSTEM 3-lb 3.1. I Operable Components 3-lb Figure 3-0 ASI vs Fraction of Rated Power 3-3a 3.1.2 Heatup and Cooldown Rates 3-4 Figure 3-I Pressure - Temperature Limits for Heatup 3-9 Figure 3-2 Pressure - Temperature Limits for Cooldown 3-IO Figure 3-3 Pressure - Temperature Limits for Hydro 3-11 3.1.3 Minimum Conditions for Criticality 3-I2 3 .1.4 Maximum Primary Coolant Radioactivity 3-17 3.1.5 Primary Coolant System Leakage Limits 3-20 3.1.6 Maximum PCS Oxygen and Halogen Concentration 3-23 3.1. 7 Primary and Secondary Safety Valves 3-25 3.1.8 Overpressure Protection Systems 3-25a 3 .1. 9 Shutdown Cooling 3-25d 3.2 CHEMICAL AND VOLUME CONTROL SYSTEM 3-26 3.3 EMERGENCY CORE COOLING SYSTEM 3-29 3.4 CONTAINMENT COOLING 3-34 3.5 STEAM AND FEEDWATER SYSTEMS 3-38 3.6 CONTAINMENT SYSTEM 3-40 Table 3.6.I Containment Penetrations and Valves 3-40b 3.7 ELECTRICAL SYSTEMS 3-4I 3.8 REFUELING OPERATIONS 3-46 3.9 Deleted 3-50 i

Amendment -1.§4

3.1 . PRIMARY COOLAN~YSTEM Applicability Applies to the operable status of the primary coolant system.

Objective To specify certain conditions of the primary coolant system which must be met to assure safe reactor operation.

Specifications 3.1.1 Operable Components

a. At least one primary coolant pump or one shutdown cooling pump with a flow rate greater than or equal to 2810 gpm shall be in operation whenever a change is being made in the boron concentration of the primary coolant and the plant is operating in cold shutdown or above, except during an emergency loss of coolant flow situation.

Under these circumstances, the boron concentration may be increased with no primary coolant pumps or shutdown cooling pumps running.

b. Four primary coolant pumps shall be in operation whenever the reactor is operated above hot shutdown, with the following exception:

Before removing a pump from service, thermal power shall be reduced as specified in Table 2.3.l and appropriate corrective action implemented. With one pump ant of service, return the pump to service within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (return to four-pump operation) or be in hot shutdown (or below) with the reactor tripped (from the C-06 panel, opening the 42-01 and 42-02 circuit breakers) within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Start-up (above hot shutdown) with less than four pumps is not permitted and power operation with less than three pumps is not permitted.

c. The measured four primar¥ coolant pumps operating reactor vessel flow shall be 140.7 x 10 lb/hr or greater, when corrected to 532°F.

d. Both steam generators shall be capable of performing their heat transfer function whenever the average temperature of the primary coolant is above 300°F.

e. Deleted 3-1 b Amendment No. 3-l, 8§., +/-8, ll9' 34' +/-3-7

3 .1 e

PRIMARY COOLANT SYSTEM (Cont'd) 3.1.1 Operable Components {cont'd)

h. Forced circulation (starting the first primary coolant pump) shall not be initiated unless one of the following conditions is met:

(1) Primary coolant cold leg temperature is > 430°F.

(2) PCS cold leg temperature is s 430°F and S/G secondary temperature is less than PCS cold leg temperature.

(3) Shutdown cooling is isolated from the PCS AND PCS cold leg temperature is > 210°F and S/G secondary temperature is less than l00°F higher than PCS temperature.

(4) Shutdown cooling is isolated from the PCS AND PCS cold leg temperature is ~ 170°F and s 210°F AND S/G secondary temperature is less than 20°F higher than PCS cold leg temperature.

(5) Shutdown cooling is isolated from the PCS AND PCS cold leg temperature is ~ 120°F and < 170°F AND S/G secondary temperature is less than I00°F higher than PCS cold leg temperature.

i. The PCS shall not be heated or maintained above 300°F unless a minimum of 375 kW of pressurizer heater capacity is available from both buses ID and IE. Should heater capacity from either bus ID and IE fall below 375 kW, either restore the inoperable heaters to provide at least 375 kW of heater capacity from both buses ID and IE within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in hot shutdown within the next I2 hours.

When primary coolant boron concentration is being changed, the process must be uniform throughout the primary coolant system volume to prevent stratification of primary coolant at lower boron concentration which could result in a reactivity insertion.

Sufficient mixing of the primary coolant is assured if one shutdown cooling or one primary coolant pump is in operation.11 1 The shutdown cooling pump will circulate the primary system volume in less than 60 minutes when operated at rated capacity. By imposing a minimum shutdown cooling pump flow rate of 28IO gpm, sufficient time is provided for the operator to terminate the boron dilution under asymmetric flow conditions. 151 The pressurizer volume is relatively inactive, therefore will tend to have a boron concentration higher than rest of the primary coolant system during a dilution operation.

Administrative procedures will provide for use of pressurizer sprays to maintain a nominal spread between the boron concentration in the pressurizer and the primary system during the addition of boron. 121 3-Id Amendment No fH-, 8-S, H-7, .f-l-8, +a-+/--,

3*. I. 9 s.HUTDOWN coouNSDc)

Specification 3.1.9.1 One PCS loop or SDC train shall be in operation providing ~2810 gpm flow through the reactor core, and at least two of the means of decay heat removal listed below shall be OPERABLE:

1. SDC train A consisting of an OPERABLE SDC pump and an OPERABLE heat flow path to Lake Michigan.

2. SDC train B consisting of an OPERABLE SDC pump and an OPERABLE heat flow path to Lake Michigan.

3. PCS loop 1 consisting of an OPERABLE Primary Coolant Pump and an OPERABLE Steam Generator and secondary water level ~-84%.

4. PCS loop 2 consisting of an OPERABLE Primary Coolant Pump and an OPERABLE Steam Generator and secondary water level ~-84%.

Applicability Specification 3.1.9.1 applies when there is fuel in the reactor, with PCS Temperature is >200°F and ~300°F.

Exception

1. All flow through the reactor core may be intentionally stopped for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> provided:

a. No operations are permitted that would cause reduction of the PCS boron concentration, and

b. Core outlet temperature stays ~l0°F below saturation temperature.

Action

1. With fewer OPERABLE means of decay heat removal than required:

a. Immediately initiate corrective action to return a second loop or train to OPERABLE status, and

b. Maintain PCS temperature as low as practical with available equipment.

c. If a SDC train is available, be <200°F within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

2. With less flow through the core than required:

a. Immediately suspend all operations involving a reduction in PCS boron concentration, and

b. Immediately initiate corrective action to return a loop or train to operation providing flow through the core.

3-25d Amendment No.

3*. l. 9 SHUTDOWN COOLIN~SDC)

Speci fi cation 3.1.9.2 One SDC train shall be in operation ~roviding ~2810 gpm flow through the reactor core, and at least two of the means of decay heat removal listed below shall be OPERABLE:

I. SDC train A consisting of an OPERABLE SDC pump and an OPERABLE heat flow path to Lake Michigan.

2. SDC train B consisting of an OPERABLE SDC pump and an OPERABLE heat flow path to Lake Michigan.

3. PCS loops 1 and 2, each with an OPERABLE steam generator and secondary level ~-84%.

Applicability Specification 3.1.9.2 applies when there is fuel in the reactor, with PCS Temperature is <200°F and the PCS loops filled.

Exceptions

1. All flow through the reactor core may be intentionally stopped for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> provided:

a. No operations are permitted that would cause reduction

. of the PCS.boron concentration or PCS inventory, and

b. Core outlet temperature stays ~200°F, and

c. Two SDC trains are OPERABLE.

2. One or both SDC trains may be intentionally rendered inoperable for testing or maintenance provided:

a. One PCS loop or SDC train is providing flow through the reactor core, and

b. Core outlet temperature stays ~200°F, and

c. Each steam generator secondary water level is ~-84%.

Action

1. With fewer OPERABLE means of decay heat removal than required:

a. Immediately initiate corrective action to return a second loop or train to OPERABLE status, and

b. Maintain PCS temperature as low as practical with available equipment.

2. With less flow through the core than required:

a. Immediately suspend all operations involving a reduction in PCS boron concentration, and

b. Immediately initiate corrective action to return a loop or train to operation providing flow through the core.

3-25e Amendment No.

e 3.1.9 SHUTDOWN COOLING (SDC)

Specification 3.1.9.3 One SDC train shall be in operation providing ~1000 gpm flow through the reactor core, and at least two of the means of decay heat removal listed below shall be OPERABLE:

1. SDC train A consisting of an OPERABLE SDC pump and an OPERABLE heat flow path to Lake Michigan.

2. SDC train B consisting of an OPERABLE SDC pump and an OPERABLE heat flow path to Lake Michigan.

Applicability Specification 3.1.9.3 applies when there is fuel in the reactor, with PCS Temperature is <200°F and the PCS loops NOT filled.

Exceptions

1. All flow through the reactor core may be intentionally stopped for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> provided:

a. No operations are permitted that would cause reduction of the PCS boron concentration or PCS inventory, and

b. Core outlet temperature stays ~200°F, and

c. Two SDC trains are OPERABLE.

2. One or both SDC trains may be intentionally rendered inoperable for testing or maintenance provided:

a. One SDC train is providing flow through the reactor core, and

b. Core outlet temperature stays ~200°F, and

c. The refueling cavity water level is ~647'.

Action

1. With fewer OPERABLE means of decay heat removal than required:

a. Immediately initiate corrective action to return a second train to OPERABLE status, and

b. Maintain PCS temperature as low as practical with available equipment.

2. With less flow through the core than required:

a. Immediately suspend all operations involving a reduction in PCS boron concentration, and

b. Immediately initiate corrective action to return a train to operation providing flow through the core.

3-25f Amendment No.

3.1 PRIMARY COOLANT SYSTEM (PCS) 3.1.9 SHUTDOWN COOLING BASIS The Shutdown Cooling (SDC) specifications require a minimum flow be maintained through the reactor core and two methods of decay heat removal to be OPERABLE, in each of three situations, PCS temperature 200°F to 300°F, PCS temperature below 200°F with the loops filled, and PCS temperature below 200°F with the loops not filled. "Loops Filled" means the PCS loops are intact, not blocked by dams, and totally filled with coolant.

The requirement to maintain 2810 gpm flow through the reactor core when the PCS loops are filled is based on an analysis of potential dilution events. Maintenance of this flow assures that indication of increasing count rate will be available to warn the operator and allow compensating action. The requirement to maintain 1000 gpm flow through the reactor core when the loops are not filled assures mixing of the PCS while allowing flow to be reduced to avoid vortexing in the SDC suction piping.

The 1000 gpm is based on operating experience, rather on analysis. With flow less than 2810 gpm, Specification 3.10.1 imposes additional requirements for Shutdown Margin and limits charging pump operability.

Maintaining flow through the reactor core also allows use of the SDC

.temperature indication to determine core outlet temperature when the core outlet thermocouples are not in service.

Natural circulation is adequate for decay heat removal, however it may not provide adequate mixing of the PCS coolant during PCS boron concentration changes or inadvertent dilution events. Therefore, forced circulation is required except during short intervals when the required loops or trains may be intentionally stopped provided additional constraints are followed.

An OPERABLE steam generator, for the purposes of this specification, must have both its primary and secondary sides intact, its tubes filled with primary coolant, and a secondary water level of at least -84% on the wide range level channels. The specified steam generator secondary water level of -84% ensures that at least one-third of the effective steam generator heat transfer area is covered and is therefore sufficient to support natural circulation in the PCS 11 *21

• In addition, there must be available a method of feedwater addition and a controllable path for steam release.

A heat flow path to the lake may vary in actual component configuration, method of operation and control, but it shall always accomplish the objective of transferring decay heat from the reactor to Lake Michigan.

As a minimum, a heat flow path requires: a shutdown cooling pump, a shutdown cooling heat exchanger, a component cooling water pump, a component cooling heat exchanger, a service water pump, and appropriate piping, valves and controls for the equipment to perform its function.

All of this equipment must be OPERABLE and must have adequate, but not necessarily redundant, electrical power.

3-25g Amendment No.

3.1 PRIMARY COOLANT SYSTEM (PCS) 3.1.9 SHUTDOWN COOLING {Continued)

The shutdown cooling trains at Palisades are not totally independent since they share common suction and discharge piping including valves M0-3015, M0-3016, CV-3006, CV-3025 and CV-3055. Similarly, the Service Water and Component Cooling Water systems are each comprised of two trains which are electrically independent, but not mechanically independent. The arrangement of each of these systems is illustrated in the associated chapters of the FSAR.

Operation of the shutdown cooling trains is limited to when the PCS temperature is below 300°F because, although the original design of the system was for 325°F, the maximum temperature used in the stress analysis of the shutdown cooling system piping was 300°F.

With the PCS temperature >200°F and ~300°F, a single primary coolant loop or a single shutdown cooling train provides sufficient heat removal capability for removing decay heat. Requiring a second means of decay heat removal to be operable provides an back up in the event of a component failure.

With the PCS temperature ~200°F the SDC trains are the normal means of decay heat removal. If both PCS loops are filled and intact, use of the PCS is permitted as a back up means of decay heat removal to permit maintenance or testing of SDC components. If a failure of the operating SDC train required use of the PCS for decay heat removal, temperatures could rise above 200°F but boiling in the steam generators would then provide a method of decay heat removal.*

With the PCS temperature ~200°F with the loops not filled, the PCS cannot be used as a method of decay heat removal. Therefore, two SOC trains are required. The loops are considered "not filled" if it has been drained so air has entered the loops and has not yet been removed. Once the PCS loops have been drained to any extent {to install steam generator nozzle dams for example) there could be sufficient air trapped in the steam generator u-tubes to prevent natural circulation.

The balance of equipment which comprises a heat flow path, {shutdown cooling heat exchanger, component cooling flow path, service water pump, and etc.) must be operated as necessary so as to maintain the PCS temperature and heatup rate within limits. This equipment is manually operated, and has no provision or requirement for automatic actuation during shutdown conditions. During periods when this equipment is required to be OPERABLE, but when PCS temperature and heat load do not require it to be in operation, required components may be temporarily isolated from the cooling flow path in order to perform testing, provided the components themselves are not disabled or rendered inoperable.

3-25h Amendment No.

3 .1 ~RIMARY COOLANT ~TEM 3.1.9 SHUTDOWN COOLING (PCS)

(Continued)

An exception to the requirement for continuous circulation through the reactor core is provided. Both SOC and PCS circulation may be stopped for up to one hour provided actions are taken to prevent dilution or draining of the PCS and to avoid situations that could produce steam in the reactor vessel. During periods without forced circulation, admission of water with less Boron concentration than currently in the PCS could collect in a localized pocket and present a potential reactivity addition upon restart of forced circulation. Maintaining the temperature well below boiling ensures that availability of single phase natural circulation. The one hour time limit is not based on analysis. It was chosen to allow testing (such as test closure of containment isolation or shutdown cooling suction valves which require or result in stopping shutdown cooling flow) or minor maintenance, but to restrict the time without mixing and circulation of the PCS.

An exception to the requirement to have heat flow paths to the lake operable has also been provided, when below 200°F. Both heat flow paths may be made inoperable provided that adequate means are provided to assure that decay heat removal is available. In addition, core outlet temperature must be maintained below 200°F, PCS heatup rate must remain within Technical Specification limits, and circulation must be maintained through the reactor core.

In the condition where the PCS loops are filled and both steam generators have sufficient secondary water level, the PCS may be relied upon as the means of decay heat removal allowing maintenance or testing of SOC, Component Cooling or Service water components.

In the condition where the reactor vessel head has been removed and the refueling cavity has been filled for refueling, the mass of water in the pool provides a passive means of decay heat removal. When the cavity is filled to ~647' elevation, this passive heat sink may be relied upon as the means of decay heat removal allowing maintenance or testing of SOC, Component Cooling, or Service water components.

During the exercising of these exceptions, operations which could drain the PCS and thereby cause a loss of, or a failure to regain, shutdown cooling are not allowed. This restriction against reducing PCS inventory does not apply to operations, such as pump flow testing, which may cause relatively minor changes in PCS inventory. The restriction is intended to apply to operations which might actually drain water from the PCS such that inventory could not be quickly regained.

References (1) ABB/CE Letter OPS-91-0496, "Minimum S/G Level Required to Support Natural Circulation Decay Heat Removal."

(2) Consumers Power Company Engineering Analysis EA-GFP-90-03, Revision 0, "Technical Review of ABB/CE Letter OPS-91-046." '.

3-25i Amendment No.

3.3 EMERGENCY C~ COOLING SYSTEM (Continued) ~

g. HPSI pump operability shall be as follows:

1) If the reactor head is installed, both HPSI pumps shall be rendered inoperable when:

a. The PCS temperature is <260°F, or

b. Shutdown cooling isolation valves M0-3015 and M0-3016 are open.

2) Two HPSI pumps shall be operable when the PCS temperature is

> 300°F.

3) One HPSI pump may be made inoperable when the reactor is subcritial provided the requirements of Section 3.3.2.c are met.

4) HPSI pump testing may be performed when the PCS temperature is <430°F provided the HPSI pump manual discharge valve is closed.

3.3.3 Prior to returning to the Power Operation Condition after every time the plant has been placed in the Refueling Shutdown Condition, or the Cold Shutdown Condition for more than 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and testing of Specification 4.3.h has not been accomplished in the previous 9 months, or prior to returning the check valves in Table 4.3.l to service after maintenance, repair or replacement, the following conditions shall be met:

a. All pressure isolation valves listed in Table 4.3.1 shall be functional as a pressure isolation device, except as specified in

b. Valve leakage shall not exceed the amounts indicated.

b. In the event that integrity of any pressure isolation valve specified in Table 4.3.1 cannot be demonstrated, at least two valves in each high pressure line having a non-functional valve must be in and remain in, the mode corresponding to the isolated condition. 111 1

Motor-operated valves shall be placed in the closed position and power supplies deenergized.

3-30 Amendment No. ~1, J~J, JJl, 131 April 26, 1990

3.3

• EMERGENCY CORE COOLING SYSTEM Basis (continued) demonstrate that the maximum fuel clad temperatures that could occur over the break size spectrum are well below the melting temperature of zirconium (3300°F).

Malfunction of the Low Pressure Safety Injection Flow control valve could defeat the Low Pressure Injection feature of the ECCS; therefore, it is disabled in the 'open' mode (by isolating the air supply) during plant operation. This action assures that it will not block flow during Safety Injection.

The inadvertent closing of any one of the Safety Injection bottle isolation valves in conjunction with a LOCA has not been analyzed.

To provide assurance that this will not occur, these valves are electrically locked open by a key switch in the control room. In addition, prior to critical the valves are checked open, and then the 480 volt breakers are opened. Thus, a failure of a breaker and a switch are required for any of the valves to close.

Insuring both HPSI pumps are inoperable when the PCS temperature is

<260°F or the shutdown cooling isolation valves are open eliminates

.PCS mass additions due to inadvertent HPSI pump starts. Both HPSI pumps starting in conjunction with a charging/letdown imbalance may cause 10CFR50 Appendix G limits to be exceeded when the PCS temperature is <260°F. When the PCS temperature is ~ 430°F, the pressurizer safety valves ensure that the PCS pressure will not exceed 10CFR50 Appendix G.

The requirement to have both HPSI trains operable above 300°F provides added assurance that the effects of a LOCA occurring under LTOP conditions would be mitigated. If a LOCA occurs when the primary system temperature is less than or equal to 300°F, the pressure would drop to the level where low pressure safety injection can prevent core damage. Therefore, when the PCS temperature is

~260°F and ~300°F operation of the HPSI system would not cause the 10CFR50 Appendix G limits to be exceeded nor is HPSI system operation necessary for core cooling.

HPSI pump testing with the HPSI pump manual discharge valve closed is permitted since the closed valve eliminates the possibility of pump testing being the cause of a mass addition to the PCS.

References (1) FSAR, Section 9.10.3; (2) FSAR, Section 6.1, (3) FSAR, Section 14.17 (4) Letter, H.G.Shaw (ANF) to R.J.Gerling (CPCo), "Standard Review Plan Chapter 15 Disposition of Events Review for Changes to Technical Specifications Limits for Palisades Safety Injection Tank Liquid Levels", April 11, 1990.

3-33 Amendment No. -ti-, .§.l., +/-9-l, -l-l-7, +/-3-1, ~'

3.5

• STEAM AND FEEDWATER SYSTEMS Applicability Applies to the operating status of the steam and feedwater systems.

Objective To define certain conditions of the steam and feedwater system necessary to assure adequate decay heat removal.

Specifications 3.5.1 The primary coolant shall not be heated above 300°F unless the following conditions are met:

a. Both electric driven Auxiliary Feedwater, Pumps and one fire protection pump shall be operable. Th~ steam driven pump shall be operable prior to making the reactor critical.

b. The Auxiliary Feedwater System Instrumentation shall meet the minimum operability requirements addressed in Technical Specification 3.17.

c. All flow control valves associated with the Auxiliary Feedwater System shall be operable.

d. All valves, interlocks and piping associated with the above components required to function during accident conditions shall be operable.

e. A minimum of 100,000 gallons of water in the condensate storage and primary coolant system makeup tanks combined.

f. The main steam stop valves shall be operable and capable of closing in five seconds or less under no-flow conditions.

3.5.2 With the Primary Coolant System at a temperature greater than 300°F, the requirements of Specification 3.5.1 may be modified to permit the following conditions to exist. If the system is not restored to meet the requirements of Specification 3.5.1 within the time period specified below, refer to Specification 3.5.3.

a. One. auxiliary feedwater pump may be inoperable for a period of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

b. Two auxiliary feedwater pumps may be placed in manual, for testing, for a period of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

3-38 Amendment No. es, 9e

3.5 . STEAM AND FEEDWATER SYSTEMS (Cont'd) 3.5.2 (Continued)

c. The fire water makeup to the Auxiliary Feedwater Pump Suction (P-8A and P-88) may be inoperable for a period of 7 days provided the pump service water makeup to P-8C, pump P-8C, and its corresponding flow control valves are operable.

d. The service water makeup to the Auxiliary Feedwater Pump Suction (P-8C) may be inoperable for a period of 7 days provided the fire water makeup to P-8A & P-88, pumps P-8A and P-88 and their corresponding flow control valves are operable.

e. One flow control valve on each train may be inoperable for a period of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> provided the corresponding redundant flow control valve and a pump in the other pipe train are operable.

3.5.3 With the Primary Coolant System at a temperature greater than 300°F and if the system does not satisfy the requirements of Specification 3.5.1 or the conditions of Specification 3.5.2 except as noted in Specification 3.5.4, the reactor shall be placed in hot standby within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, hot shutdown within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in cold shutdown within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

3.5.4 With all Auxiliary Feedwater Pumps inoperable immediately initiate corrective action to restore at least one Auxiliary Feedwater Pump to OPERABLE status as soon as possible and reduce power within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> to the lowest stable power level consistent with reliable Main Feedwater System operation.

3-38a Amendment No. 96

3.7. ELECTRICAL SYSTEMS Applicability Applies to the availability of electrical power for the operation of plant components.

Objective To define those conditions of electrical power availability necessary to provide for safe reactor operation and the continuing availability of engineered safety features.

3.7.I Specifications The primary coolant system shall not be heated or maintained at temperatures above 300°F if the following electrical systems are not operable:

a. Station power transformer I-2 (2400 V).

b. Start-up transformer I-2 (2400 V).

c. 2400 V engineered safeguards buses IC and ID.

d. 480 V distribution buses II and I2.

e. MCC No I, 2, 7 and 8.

f. I25 V d-c buses No I and 2.

g. Four preferred a-c buses.

h. Two station batteries and the d-c systems including at least one battery charger on each bus.

i. Both diesel generators, with a minimum of 2500 gallons of fuel in each day tank and a minimum of I6,000 gallons of fuel in the underground storage tank.

j. Switchyard battery and the d-c system with one battery charger.

k. 240 V a-c power panels No I and 2, and their associated ACB breaker distribution systems.

1. 2400 V bus IE.

3.7.2 The requirements of Specification 3.7.I may be modified to the extent that one of the following conditions will be allowed. If any of the provisions of those exceptions are violated, the reactor shall be placed in a hot shutdown condition within I2 hours. If the violation is not corrected within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, the reactor shall be placed in a cold shutdown condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

3-4I Amendment No. -l§a.

3.7. ELECTRICAL SYSTEMS (Continued) 3.7.3 SHUTDOWN COOLING ELECTRICAL REQUIREMENTS With the primary coolant system at ~300°F, and with fuel in the reactor, the shutdown cooling train(s) shall be electrically powered as follows:

a. If one train of shutdown cooling is required to meet specification 3.I.9:

I. The appropriate engineered safeguards bus (IC or ID) shall be operable and capable of being supplied by offsite power and an operable diesel generator.

2. Have two trains of shutdown cooling operable, and meet all the requirements of 3.7.3.b below.

b. If two trains of shutdown cooling are required to meet specification 3.I.9, one engineered safeguards bus (IC or ID) shall be operable and supplied by offsite power while the other engineered safeguards bus (ID or IC) is operable and capabl*e of being supplied by an operable diesel generator.

ACTION With less than the required electrical sources operable:

A. Immediately initiate action to suspend core alterations, B. Immediately initiate action to suspend movement of irradiated fue 1, C. Immediately suspend crane operations over irradiated fuel, D. Immediately suspend operations with a potential for draining the PCS or fuel pool, E. Immediately initiate action to restore the required electrical sources to operable status.

3-45a Amendment No.

3.7 ELECTRICAL SYSTEM (Continued) 3.7.3 SHUTDOWN COOLING ELECTRICAL REQUIREMENTS (Continued)

BASIS The operability of the minimum specified power sources and associated distribution systems during shutdown and refueling ensures that:

1. The plant can be maintained in the shutdown or refueling operation condition for extended time periods, and

2. Sufficient control capability is available for maintaining the plant status.

When a single train of shutdown cooling must be operable to meet the minimum equipment operability requirements to remove decay heat, the train must still function following the loss of one electric supply (offsite power or diesel generator).

When two trains of shutdown cooling must be operable to meet the minimum equipment operability requirements to remove decay heat, the loss of any single pump or the loss of one electrical supply (offsite power or diesel generator) must still leave a shutdown cooling train operable.

The action statements will minimize the occurrence of postulated events, however, they should not preclude the orderly completion of an activity, such as fuel movement or crane operation, in order to get into a safe and conservative position.

3-45b Amendment No.

Table 3.17.4 (Cont'd)

Minimum MinimumPermissible O~erable Degree of Bypass No Functional Unit C annels Redundancy Conditions

8. Pressurizer Wide 2 (m, n, o) None Not required in Ran~e Water Level Cold or Indication Refueling Shutdown

9. Pressurizer Code 1 ~er None Not Required Safety Relief Valves Va ve below 300°F Position Indication tAcoustic Monitor or emperature Indication)

10. Power Operated Relief 1 ~er None Not required when Valves (Acoustic Va ve PORV isolation Monitor or Temperature valve is closed Indication) and its indication system is operable

11. PORV Isolation Valves 1 ~er None Not required when Position Indication Va ve reactor is depressurized and vented through a vent ~1.3 sq.in.

12. Subcooling Margin 1 None Not required Monitor below 300°F

13. Auxiliary Feed Flow 1 pe~ None Not required Rate Indication fl ow hi below 300°F Control Valve

14. Auxiliary Feedwater 2 per 1 Not required Actuation System steam below 300°F Sensor Channels generator 161

15. Auxiliary Feedwater 2ltl 1 Not required Actuation System below 300°F Actuation Channels

16. Excore Detector 1(g) None Not Required Deviation Alarms Below 25% of Rated Power

17. Axial Shape Index 2(i) 1 Not Required Alarm Below 25% of Rated Power

18. Reactor Vessel 2ij,k,l,m) None Not Required Water Level Below 300°F

19. Core Exit 4/core None Not required Thermocouples ~~:~rant below 300°F 3-81a Amendment No. frl-, 68, %, -H-5, H-8, 29, HJ

3:25 ALTERNATE SHUTDOWN SYSTEM LIMITING CONDITION FOR OPERATION 3.25.1 The Alternate Shutdown System instrumentation and components shown in Table 3.25.1 shall be OPERABLE. Operability shall be demonstrated by performing the surveillances in accordance with Section 4.21.

APPLICABILITY:

Reactor coolant temperature~ 300°F.

ACTION:

a. With less than the "Minimum Equipment" in Table 3.25.1 Operable, restore the inoperable equipment to Operable within 7 days, or provide equivalent shutdown capability and restore the inoperable equipment to Operable within 60 days; or be in Hot Shutdown within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and Cold Shutdown within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

b. The provisions of Specification 3.0.3 and 3.0.4 do not apply.

The operability of the Alternate Shutdown System ensures that any fire will not preclude achieving safe shutdown. The Alternate Shutdown System components are independent of areas where a fire could damage systems normally used to shut down the reactor. This capability is consistent with Regulatory Guide 1.97 and Appendix R to 10CFR50.

3-134 Amendment No . .J-2-2., -l-4-e

• Table 4.2.2 (Contd)

Minimum Frequencies for Equipment Tests

12. lodi ne Removal System The Iodine Removal System shall be demonstrated operable:

a. At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path that is not locked, sealed or otherwise secured in position, is in its correct position.

b. At least once per 6 months by:

1. Verifying that tanks T-102 and T-103 contain the minimum required volumes.

2. Verifying the concentration of hydrazine in T-102 and sodium hydroxide in T-103.

c. At least once per refueling cycle, during shutdown, by verifying that each automatic valve in the flow path actuates to its correct position.

13. Containment Purge and Ventilation Isolation Valves The Containment Purge and Ventilation Isolation Valves shall be determined closed:

a. At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by checking the valve position indicator in the control room

b. At least once every 6 months by performing a leak rate test between the valves.

14. Shutdown Cooling To meet the shutdown cooling requirements of Section 3.1.9:

a. The required reactor coolant pump(s), if not in operation should be determined to be OPERABLE once per 7 days by verifying correct breaker alignments and indicated power availability.

b. The required steam generator(s) shall be determined OPERABLE by verifying the secondary water level to be ~-84% at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

c. At least one coolant loop or train shall be verified to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

4-15b Amendment No. 81-, 9G,

TABLE 4.21.1 (Continued)

ALTERNATE SHUTDOWN MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS Surveillance Channel Description Function Frequency Surveillance Method

7. Source Range Neutron Monitor a. Test Prior to a. Internal test signal (performed under Table 4.1.3)

CNI-1/3C) startup141

8. Auxiliary Feedwater Low suction a. Calibrate Refueling a. Apply known pressure to pressure sensor Pressure switch Cycle (PS-0741D)

9. SIRW Tank Level Indication a. Check111 Quarterly a. Compare independent level readings CLI-03328)

b. Calibrate Refueling b. Apply known differential pressure to level sensor Cycle

10. Auxiliary Feedwater Flow Rate 121 a. Calibrate Refueling a. Apply known differential pressure to sensor(s)

Indication Cycle CFI-07278)

CFI-07498)

11. Auxiliary Feedwater Flow Control 131 a. Check Refueling a. Verify Control Valves (CV-0727 & CV-0749) Cycle

12. Auxiliary Feedwater Pump Inlet a. Check Refueling a. Verify Control Steam Valve CCV-05228) Cycle (1) Quarterly check are not required when the plant is less than 300"F.

(2) Satisfies Table 4.1.3-15 Requirement.

(3) See Specification 4.9b.

(4) Prior to each startup, if not done previous week.

4-88 Amendment No. ii, ~. m,