ML20066E815

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Proposed Changes to Tech Spec 3/4.7.1.2 Re Auxiliary Feedwater Sys
ML20066E815
Person / Time
Site: Calvert Cliffs Constellation icon.png
Issue date: 11/05/1982
From:
BALTIMORE GAS & ELECTRIC CO.
To:
Shared Package
ML20066E811 List:
References
NUDOCS 8211170225
Download: ML20066E815 (11)
v • d • e


Text

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ATTACHMENT 1 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 = Total 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 feedwatgr 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 regve 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, 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 total instrument loop error band of plus 47 gpm (217 gpm total flow per leg) and minus 60 gpm (90 gpm total flow per leg).

In the spectrum of events analyzed in which automatic initiation of auxiliary feedwater occurs the nominal setting of 160 gpm allows a minimum of 10 minutes before operator action is required. At 10 minutes after automatic initiation of flow the operator is assumed to be available to increase or decrease auxiliary feedwater flow to that required for existing plant conditions.

8211170225 -

PDR ADOCK 0 00kB PDR CALVERT CLIFFS UNIT-2 B 3/4 7-2 Amendment No.

-o ATTACHMENT 2 -

B TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION

+

u MINIMUM

' TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION ru 8. CVCS ISOLATION

a. Manual (CVCS Isolation Valve Control Switches) 1/ Valve ' 1/ Valve 1/ Valve 1, 2, 3, 4 6
b. West Penetration Room / Letdown Heat Exchanger Room j Pressure - High 4 2 3 1,2,3,4 7*'

T 9. AUXILIARY FEEDWATER

$ Actuation System

a. Manual (Trip Buttons) 2 sets of 2 1 set of 2 2 sets of 2 1,2,3 6 per S/G per S/G per S/G
b. Steam Generator Level - Low 4/SG 2/SG ' 3/SG 1,2,3 -7
c. Steam Generator A P High 4/SG 2/SG 3/SG 1,2,3 7 k

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. EF

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O ATTACHMENT 3 TABLE 3.3-4 (Continued) a ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES f FUNCTIONAL UNIT TRIP VALUE ALLOWABL.E VALUES g

8. CVCS ISOLATION ru West Penetration Room / Letdown Hear f 0.5 psig <0.5 psig Exchanger Room Pressure - High
9. AUXILIARY FEEDWATER ACTUATION SYSTEM
a. Manual (trip buttons) Not Applicable Not Applicable y*= b. Steam Generator (A or B) Level- Low -194" to -149" -194" to -149" (inclusive) (inclusive) w h c. Steam Generator 4 P-High f 130.0 psid f 130.0 psid (SG-A > SG-B) .
d. Steam Generatord P-High i 130.0 psid 6.130.0 psid (SG-B > SG-A) ka n

EF

ATTACHMENT 4 TABLE 3.3-5 (Continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION - RESPONSE TIME IN SECONDS

6. Steam Generator Pressure-Low
a. Main Steam Isolation f 6.9
b. Feedwater Isolation 3 80
7. Refueling Water Tank-Low
a. Containment Sump Recirculation f80
8. Reactor Trip
a. Feedwater Flow Reduction to 5% f 20
9. Loss of Power
a. 4.16 kv Emergency Bus Undervoltage f 2.2** *

(Loss of Voltage)

b. 4.16 kv Emergency Bus Ur.dervoltage i 8.4***

(Degraded Voltage)

10. Steam Generator Level- Low
a. Steam Driven AFW Pump $.54.5
b. Motor Driven AFW Pump $ 54.5* / 14.5**

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11. Steam Generator AP-High
a. Auxiliary Feedwater Isolation f 20.0 TABLE NOTATION
  • Diesel generator starting and sequence loading delays included.
    • Diesel generator starting and sequence loading delays not included.

Offsite power available.

      • Response time measured from the incidence of the undervoltage condition to the diesel generator start sigial.

CALVERT CLIFFS - UNIT 2 3/4 3-21 Amendment No.

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ATTACH 7B7r 5 O TABLE 4.3-2 (Continued)

B ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL MODES IN WHICH E CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE

, FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED

5. CONTAINMENT SUMP RECIRCULATION (RAS)

N a. Manual RAS (Trip Buttons) N.A. N.A. R N.A.

, b. Refueling Water Tank - Low . N.A. R M 1, 2, 3

c. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3
6. CONTAINMENT PURGE VALVES ISOLATION ##
a. Manual (Purge Valve Control Switches N.A. N.A. R- N.A.

w b. Containment Radiation - High h Area Monitor 5 R M 6 w

h

7. LOSS OF POWER
a. 4.16 kv Emergency Bus Undervoltage (Loss of Voltage N.A. R M- 1,2,3
b. 4.16 kv Emergency Bus Undervoltage (Degraded Voltage N.A. R M 1, 2, 3
8. CVCS ISOLATION N.A. R M 1, 2, 3, 4 West Penetration Room /

Letdown Heat Exchange Room Pressure - High

9. AUXILIARY FEEDWATER g, a. Manual (Trip Buttons) N.A. N.A. R N.A.

3 b. Steam Generator Level-Low S R M 1, 2, 3 ft c. Steam Generator A P-High S R M .1, 2,- 3

d. Automatic Actuation Logic -N.A. N.A. M(1) 1, 2, 3
    1. Containment purge valve isolation is also initiated by SIAS (functional units 1.a,1.b and 1.c).

o ATTACHMENT 6

.'h TABLE 3.3-9 REMOTE SHUTDOWN MONITORING INSTRUMENTATION MINIMUM READOUT MEASUREMENT- GiANNELS G INSTRUMENT LOCATION RANGE PERABLE b

ru 1. Reactor Trip Breaker Indication Cable Spreading Room OPEN-CLOSE 'a breaker

2. Reactor Coolant Cold Leg Temperature 2C43 212-7050 p i
3. Pressurizer Pressure 2C43 0-4000 psia 1

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4. Pressurizer Level 2C43 0-360 inches l-g 5. Steam Generator Pressure 2C43 0-1200 psig 'l/ steam generator N

[ 6. Steam Generator Level 2C43 -401 to +63.5 inches 1/ steam generator b

k n

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.if 1

.. __ __ ._. . . - _ - . . _ . . ~ _ _ . _.

ATTACHMENT 7 -

0 TABLE 4.3-6 h

, g REMOTE SHUTOOWN MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL E. INSTRUMENT CHECK CALit3 RATION I

g 1. Reactor Trip Breaker Indication M N.A.

2. Reactor Coolant Cold Leg Temperature M R ,
3. Pressurizer Pressure M g
4. Pressurizer Level M R
5. Steam Generator Pressure M - R w 6. Steam Generator Level M R D

Y

, 8 r

a if O

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ATTACHMENT 8 g TABLE 3.3-10 POST-ACCIDENT MONITORING INSTRUMENTATION a

i MINIMUM N CHANNELS b INSTRUMENT OPERABLE ro

1. Containment Pressure 2
2. Wide Range Logarithmic Neutron Flux Monitor 2 3.. Reactor Coolant Outlet Temperature 2
4. Pressurizer Pressure 2 R 5. Pressurizer Level 2 a

43 6. Steam Generator Pressure 2/ steam generator S

7. Steam Generator Level (Wide Range) 21 steam generator
8. Auxiliary Feedwater Flow Rate 2/ steam generator
9. RCS Subcooled Margin Monitor 1
10. PORV/ Safety Valve Acoustic Flow Monitoring 1/ valve
11. PORY Solenoid Power Indication 1/ valve t

, a l

I P

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ATTACHMENT 9 -

g TABLE 4.3-10

~

POST-ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS 4 CHANNEL CHANNEL INSTRUMENT CHECK CALIBRATION

1. Containment Pressure M R ru 2. Wide Range Logarithmic Neutron Flux Monitor M N.A.
3. Reactor Coolant Outlet Temperature M R
4. Pressurizer Pressure M R
5. Pressurizer Level M R
6. Stearn Generator Pressure M R M

= 7. Steam Generator Level (Wide Range) M R Y R g 8. Auxiliary Feedwater Flow Rate M.

9. RCS Subcooled Margin Monitor M R
10. PORV/ Safety Valve Acoustic Monitor N.A. R
11. PORV Solenoid Power Indication N.A. N.A.

}

a

.EF

PLANT SYSTEMS ATTACHMENT 10 AUXILIARY FEEDV'ATER 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 cpnsist of one pump _ aligned for automatic flow initiation and one pump aligned in standby _.)

APPLICABILITY: MODES 1,2, and 3.

ACTION:

I a. With one motor driven pump inoperable:

1. Restore the inoperable motor driven pump to OPERABLE 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 />.
b. With one steam driven pump inoperable:
1. Align the standby steam driven pump to OPERABLE 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
2. Restore the inoperable steam driven pump to standby status (or OPERABLE 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 />.
c. Whenever 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 i test) a dedicated operator will be stationed at the local station with direct communication to the Control Room. Upor. completion of any testing, the subsystem required for operability will be returned to its proper status and verified in its proper status by an independent operator check.

With the requirements of 3.7.1.2.a. or 3.7.1.2.b. met, the provisions of specification 3.0.4 are not applicable.

1A standby pump shall be available for operation but aligned so that automatic flow initiation is defeated upon AFAS actuation.

CALVERT CLIFFS-UNIT 2 3/47-5 Amendment No.

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m ATTACHMENT 11 PLANT SYSTEMS SURVEILLANCE REQUIREMENTS 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 A 2800 ft. on recirculation flow. (If verification must be demonstrated during startup, surveillance tgting shall be performed upon achieving an RCS temperature 2 300 F and prior to entering MODE 1).
2. Verifying that the motor driven pump develops a Total Dynamic Head of 2 3100 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. The AFW flow control valves may be verified by observing a 160 gpm setpoint on the flow indicator controller in Control Room.
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 a modulated flow of 160 gpm + 10 gpm to each flow leg upon receipt of each auxiliary feedwater actuation system (AFAS) test signal.

1 CALVERT CLIFFS-UNIT 2 3/4 7-Sa Amendment No.

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