ML20078A621

Proposed Tech Specs Re Auxiliary Feedwater Sys Limiting Condition for Operation

ML20078A621
Person / Time
Site:	Calvert Cliffs
Issue date:	09/16/1983
From:	BALTIMORE GAS & ELECTRIC CO.
To:
Shared Package
ML20078A619	List: ML20078A616 ML20078A621
References
NUDOCS 8309230346
Download: ML20078A621 (7)

Text

PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 Two auxiliary feedwater trains consisting of one steam-driven and one motor-driven pump and associated flow paths capable of automatically initiating flow shall be OPERABLE.* (An OPERABLE steam-driven train shall consist of one pump aligned for automatic flow initiation and one pump aligned in standby.)**

APPLICABILITY: MODES 1,2 AND 3 ACTION:

a.

With any single pump inoperable, perform the following:

1.

With 13 motor-driven pump inoperable 1.

Align the standby steam-driven pump to automatic initiating status 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 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, and 11.

Restore 13(23) motor-driven pump to OPERABLE status within the next 14 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 />.

2.

With one steam-driven pump inoperable:

1.

Align the OPERABLE steam-driven pump to automatic initiating status 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 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, and li.

Restore the inoperable steam-driven pump to standby status (or automatic initiating status if the other steam-driven pump is to be placed in standby) within the next 30 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 />.

b.

With any two pumps inoperable, perform the following:

Verify within one hour that the remaining pump is aligned to automatic initiating status,that 23 motor-driven pump is operable, and that 2-CV-4550 has been exercised in the last 31 days. Restore a second pump to automatic initiating status within 72

~ hours. Otherwise, be in HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

For a period of up to 31 da including MODE 1 operation)ys following entrance into Mode 3 (up through and from the Cycle 7 Unit I startup, the automatic actuation features of the auxiliary feedwater system may be inoperable.

A standby pump shall be available for operation but aligned so that automatic flow initiation is defeated upon AFAS actuation.

CALVERT CLIFFS UNIT 1 3/47-5 9309230346 830916 DR ADOCK 05000'

c.

Whenever a subsystem /s (a subsystem consisting of one pump, piping, valves and controls in the direct flow path) required for operability is inoperable for the performance of periodic testing (e.g. manual discharge valve closed for pump

- Total Dynamic Head Test or Logic Testing) a dedicated operator /s will be stationed at the local station /s with direct communication to the Control Room. Upon completion of any testing, the subsystem /s required for operability will be returned to its proper status and verified in its proper status by an independent operator check.

d.

The requirements of Specification 3.0.4 are not applicable whenever one motor and one steam-driven pump (or two steam-driven pumps) are aligned for automatic flow initation.

PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM SURVEILLANCE REOUIREMENTS 4.7.1.2 Each auxiliary feedwater flowpath shall be demonstrated OPERABLE:

a.

At least once per 31 days by:

1.

Verifying that each steam-driven pump develops a Total Dynamic Head of 12300 ft. on recirculation flow (if verification must be demonstrated during startup, surveillance testing shall be performed upon achieving an RCS temperature 1300 F and prior to entering MODE 1).

2.

Verifying that the motor-driven pump develops a Totai Dynamic Head of 23100 ft. on recirculation flow.

3.

Cycling each testable, remote-operated valve that is not in its operating position through at least one complete cycle.

4.

Verifying that each valve (manual, power operated or automatic) in the direct flow path is in its correct position.

b.

Before entering MODE 3 after a COLD SHUTDOWN of at least 14 days by completing a flow test that verifies the flow path from the condensate storage tank to the steam generators.

c.

At least once per 18 months by verifying that each automatic valve in the flow path actuates to its correct position and each auxiliary feedwater pump automatically starts and delivers flow to each flow leg upon receipt of each auxiliary feedwater actuation system (AFAS) test signal.

I CALVERT CLIFFS UNIT 1 3/4 7-Sa

4 TABLE 3.3-9 REMOTE SHUTDOWN MONITORING INSTRLMENTATION MINihEM READOLTT MEASUREMENT CHAPNELS INSTREMENT LOCATION RANGE OPERABLE b'

l.

Wide Range Neutron Flux IC43 0.1 cps-200% Power 1

p 2.

Reactor Trip Breaker Cable Spreading OPEN-CLOSE 1/ trip breaker Indication Room 3.

Reactor Coolant Cold Leg i

Temperature IC43 212-705 F 1

4.

Pressurizer Pressure IC43 0-4000 psia 1

5 Pressurizer Level IC43 0-360 inches 1

6 Steam Generator Pressure IC43 0-1200 psig 1/ steam generator i

7 Steam (knerator Level (Wide Range)

IC43

.-401 to +63.5 inches 1/ steam generator

]

t CALVERT CLIFFS - UNIT I 3/4 3-38 4

4 l

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TABLE 4.3-6

~

REMOTE SHUTDOWN MONITORING INSTRLAENTATION SURVEILLANCE REOUIREMENTS CHAPNEL OiABNEL INSTRLAENT CHECK

. CALIBRATION 1.

Wide Range Neutron Flux M

N.A.

2.

Reactor Trip Breaker Indication M

N.A.

3.

Reactor Coolant Cold Leg Temperature M

R 4.

Pressurizer Pressure M

R 5.

Pressurizer Level M

R 6.

Steam Generator Level (Wide Range)

M R

7.

Steam Generator Pressure M

R 2

i k

Calvert Clifis - Unit 1 3/4 3-39 4

i I

i

e TABLE 3.3-10 POST-ACCIDENT MONITORING INSTRUMENTATION MINIMUM CHANNELS INSTRUMENT OPERABLE 1.

Containment Pressure 2

2.

Wide Range Logarithmic Neutron Flux Monitor 2

3.

Reactor Coolant Outlet Temperature 2

4.

Pressurizer Pressure 2

5.

Pressurizer Level 2

6.

Steam Generator Pressure

?/ steam generator 7.

Steam Generator Level (Wide Range) 2/ steam generator 8.

Feedwater Flow 2

9.

Auxiliary Feedwater Flow Rate 2/ steam generator

10. RCS Subcooled Margin Monitor 1

11. PORV/ Safety Valve Acoustic Flow Monitoring 1/ valve

12. PORV Solenoid Power Indication 1/ valve i

CALVERT CLIFFS - UNIT 1 3/4 3-41

TABLE 4.3-10 POST-ACCIDENT MONITORING INSTRLMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHA!WEL_

INSTRLMENT OiECK CALIBRATION 1.

Containment Pressure M

R 2.

Wide Range Logarithmic Neutron Flux Monitor M

N.A.

3.

Reactor Coolant Outlet Temperature M

R l

4.

Pressurizer Pressure M

R 5.

Pressurizer Level M

R 6.

Steam Generator Pressure M

R l

7.

Steam Generator Level (Wide Range)

M R

8.

Feedwater Flow M

R 9.

Auxiliary Feedwater Flow Rate M

R

10. RCS Subcooled Margin Monitor M

R

11. PORV/ Safety Valve Acoustic Monitor N.A.

R

12. PORY Solenoid Power Indication N.A.

N.A.

Calvert Cl1 ifs - Unit 1 3/4 3-42

.]

i.

1

k

- PLANT SYSTEMS BASES U = maximum number of inoperable safety valves per operating steam line

.106.5 = Power Level-High Trip Setpoint for two loop operation 46.8 = Power Level-High Trip Setpoint for single loop operation with two reactor coolant pumps operating in the same loop X = T.tal relieving capacity of all safety valves per steam line in Ibs/ hour Y = Maximum relieving capacity of any one safety valve in Ibs/ hour 3/4.7.1.2 AUXILIARY FEEDWATER SYSTEM

~ The OPERABILITY of the auxiliary feedwater system ensures that the Reactor Coolant System can be cooled down to less than 300 F from normal operating conditions in the event of a total loss of offsite power. A capacity of 400 gpm is sufficient to ensure that adequate feedwater flow is available to remove decay heat and reduce the Reactor Coolant System temperature to less than 300 F when the shutdown cooling system may be placed into operation.

Flow control valves, installed in each leg supplying the steam generators, are set to maintain a nominal flow setpoint of 160 gpm plus or minus 10 gpm for operator setting band. The nominal flow setpoint of 160 gpm incorporates a totalinstrument loop i

error band of plus 47 gpm and minus 60 gpm. The operator setting band, when combined with the instrument loop error, results in a total flow band of 90 gpm (minimum) and 217 gpm (maximum). Safety analyses show that more flow during an overcooling transient and less flow during an undercooling transient could be tolerated; i.e., flow fluctuations outside this flow band but within the assumptions used in the analyses listed below, are d

allowable.

In the spectrum of events analyzed in which automatic initiation of auxiliary feedwater occurs, the following flow conditions are allowed with an operator action time of 10 minutes.

(1)

Loss of Feedwater:

0 gpm Auxiliary Feedwater Flow (2)

Feedline Break:

0 gpm Auxiliary FeeNater hv (3)

Main Steam Line Break:

1300 gpm Auxilh.y Feedwater Flow (This being the maximum flow through the AFW suction line, with one unit requiring flow, prior to pump cavitation due to low NPSH.)

At 10 minutes after an Auxiliary Feedwater Actuation Signal the operator is assumed to be available to increase or decrease auxiliary feedwater flow to that required by existing plant conditions.

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CALVERT CLIFFS UNIT 1 B 3/4 7-2 i-i

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