ML20101H384

Proposed marked-up TS Table 2.2-1 Re Reactor Trip Sys Instrumentation Trip Setpoints & Section 3/4.5.1 Re Cold Leg Injection

ML20101H384
Person / Time
Site:	Comanche Peak
Issue date:	06/26/1992
From:	TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:
Shared Package
ML20101H379	List: ML20101H375 ML20101H384
References
NUDOCS 9206290325
Download: ML20101H384 (7)

Text

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TABLE 2.2-1 (Continued)

REACTOR TRIP SYSTEM INSTRt#tENTATION TRIP SETPOINTS o" N 5 .

TOTAL SENSOR 'g g

\

)

g ERROR g ALLOWANCE g FUNCTIONAL Unit (TA) Z (5) TRIP SETPOINT ALLOWABLE VALUE og 7

7 13. Steam (c trator Water  ; -  ;

Level - Low-Low  !

E a. Unit 1 25.0 22.08 2. 0 >25.0% of narrow >23.1% of narrow I range instrument range instrument h

] span span e

b. Unit 2 35.4 22.2 2.0 >35.4% of narrow >33.4% of narrow $

range instrummt Fange instrument g h span span Undervoltage - React a. Lld.t j 7 2 30 volts- 2 53 Its-14.

h" ""

7. 7 /, A o [*Nfo nes - aA bo D5 9) - c *cl ki 5

15. UnderIreuec'y Reacto ajJil[.4[ h [_ [0 [ > 7. z >57.1hz Coolant Pumps 4 _

^l O # E 5 7' ' H

• f N7 #bN

16. Turbit.I N p** Z

a. Low Trip System Pressure N.A. H.A. N.A. y9[psig 2[j46. 6 psig

b. Turbine Stop Valve H.A. N.A. N.A. >[1%[open > 1% open Closure

17. Safety Injection Input N.A. N.A. N.A. N.A. N.A.

from ESF

18. Reactor Trip System Interlocks

a. Intermediate Range N.A. N. A. N.A. I x 10 80 amps >6 .s 10 88 amps Neutron Flux, P-6 0

.~0 b

'^r; i

jgs2;gggg oj88gg3 P

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Attachment to TXX-92292 Page 2 of 7 EMERGENCY CORE COOLING SYSTEMS DRAFl 3/4.5.1 ACCUMULATORS COLD LEG INJECTION LIMITING CONDITION FOR OPERATION 3.5.1 Each cold leg injection accumulator shall be OPERABLE with:

a. The discharge isolation valve open with power removed,

b. Anindicatedboratedwaterlevelofbetweenh9 andh

c. A boron concentration of betweenh900fand 20[ ppm,and

d. An indicated cover pressure of between 623 and 644 psig.

APPLICABILITY: MODES 1, 2, and 3*.

ACTION: .

a. With one cold leg injection accumulator inoperable, except as a result of a closed isolation valve or the boron concentration outside the required values, restore the inoperable accumulator to OPERABLE status within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in at least HOT STANOBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />,

b. With one cold leg injection accumulator inoperable due to the isolation valve being closed, either immediately open the isolation valve or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. "

c. With the boron concentration of one cold leg injection accumulator outside the required limit, restore the boron concentration to within the required limits within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.5.1.1 Each cold leg injection accumulator shall be demonstrated OPERABLE:

a. At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by: *

1) Verifying the indicated borated water volume and nitrogen cover-pressure in the tanks, and

• Pressurizer pressure above 1000 psig.

COMANCHE PEAK - UNITS 1 AND 2 3/4 5-1 )

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-Attachment to TXX-92292- i Page 3 of 7-

. DRAi?T

. PiANT SYSTEMS 3/4.7.8 PRIMARY PLANT VENTILATION SYSTEM - ESF FILTRATION UNITS l LIMITING CONDITION FOR OPERATION 3.7.8 Two independent ESF Filtration Trains shall be OPERABLE.

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

ACTION:

a. With one ESF Filtration Train inoperable, restore the inoperable ESF Filtration Tr:.in to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 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 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />,

b. With the inability to reach and maintain a negativt oressure in the negative pressure envelope of the uxili[ry Safeguaeds, and Fuel Buildings greater than or equal to >0.05tffn,ch water gauge, restore the PRIMARY PLANT VENTILATION SYSTEM to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 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 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

c. With the-inability to reach and maintain a negative pressure in the negative pressure envelope of the Auxiliary, Safeguards, and Fuel Buildings greater than or equal to 0.01 inch water gauge, restore the PRIMARY PLANT VENTILATION SYSTEM'S ability to maintain a negative pressure of greater than or equal to 0.01 inch water gauge within 7 days or be in at least HOT STANDBY within the next 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 followirg 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

SURVEILLANCE REQUIREMENTS 4.7.8 'Each ESF Filtration Tiain shall be demonstrated OPERABLE:

a. At least once per 31 days on a STAGGERED ' TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that each ESF Filtration Train operates for at least 10 continuous hours with the heaters operating;

b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire, or chemical release in any ventilation zone communi-cating with the system by:

L -1) Verifying that each ESF Filtration Unit satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 1.0% by using the test procedure guidance in Regula-tory Positions C.5.a. C.5.c, and C.5.d of Regulatory Guide 1.52, COMANCHE PEAK - UNITS 1 AND 2 3/4 7-21

Attachment to TXX-92292 Page 4 of 7 { -

PLANT SYSTEMS SURVEILLAN(E REQUIREMENTS (Continued) ____

Revision 2, Aarch 1978*, and verifying the flow rate is 15,000 cfm i 10% per ESF Filtration Unit when tested in accordance with ANSI N510-1980; and

2) Verifying, within 31 days after removal, that a laboratory anal-ysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guice 1.52, Revi-sion 2, March 19788, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978*, for a methyl iodide penetration of less than 1.0%;

c. After every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of charcoal adsorber operation, by verifying, within 31 days after removal, that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Posi-tion C.6.b of Regulatory Guide 1.52, Revision 2, March 1978*, meets the laboratory testing criteria of Regulatory Position C.6.* of Regu-latory Guide 1.52, Revision 2, March 1978*, for a methyl iocide pene-tration of less than 1.0%;

d. At least once per 18 months by:

1) Verifying that the total pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 8.5 inches Water Gauge while operating each ESF Filtration Unit at a flow rate of 15,000 cfm i 10%,

2) Verifying that each ESF Filtration Unit starts on a Safety @

Injection test signal, k

3) Verifying that the heaters dissipate 100 1 5 kW when tested in accordance with ANSI H510-1980, and

4) Verifying that the train maintains the negative pressure envelope of the Auxiliary, Safeguards, and Fuel Buildings at a negativepressureofgreaterthanorequalto{D.0$(inchwater gauge relative to the outside atmosphere;

e. After each complete or partial replacement of a HEPA filter bank, by verifying that the associated ESF Filtration Unit satisfies the in-place penetration and bypass leakage testing acceptance criteria of less than 1.0% in accordance with ANSI N510-1980 for a 00P test aero-sol while operating the associated ESF Filtration Unit at a flow rate of 15,000 cfm i 10%; and

f. After each complete or partial replacement of a charcoal adsorber bank, by verifying that the associated ESF Filtration Unit satisfies the in place penetration and bypass leakage testing acceptance crite-ria of less than 1.0% in accordance with ANSI N510-1980 for a halo-genated hydrocarbon refrigerant test gas while operating the associ-ated ESF Filtration Unit system at a flow rate of 15,000 cfm 2 10%.

• ANSI H510-1980 and ANSI H509-1980 shall be used in place of ANSI N510-1975 and ANSI N509-1976, respectively.

COMANCHE PEAK - UNITS 1 AND 2 3/4 7-22

l l Attachment to 1XX-92292 Page 5 of 7 DRAFT TABLE 3.7-3 AREA TEMPERATURE MONITORING MAXIMUM AREA TEMPERATURE LIMIT (*F)

Normal Abnormal Conditions Conditions Electrical and Control Building #

1. g Normal Areas 04 131 Control Room Main Level (E1, 830'-0") 80 104 Control Room Technical Support Area (El. 840'-6") 104 104 UPS/ Battery Rooms 104 113 chiller Equipment Areas 122 131

2. Fuel Building Normal Areas 104 131 Spent Fuel Pool Cooling Pump Rooms t122 131

3. Safeguards Buildings Normal Areas 104 131 t AFW, RHR, SI, Containment Spray Pump Rooms 122 131 ,

RHR Valve and Valve Isolation Tank Rooms 122 131 '

RHR/CT Heat Exchanger Rooms 122 131 Diesel Generator Area 122 131 Diesel Generator Equipment Rooms 130 131 }

Day Tank Room 122 131

4. Auxiliary Building Normal Areas 104 131 CCW, CCP Pump Rooms 122 131 CCW Heat Exchanger Area 122 131 CVCS Valve and valve Operating Rooms 122 131 i Auxiliary Steam Drain Tank Equipment Room 122 131 Waste Gas Tank Valve Operating Room 122 131

5. Service Water Intake Structure 127 131

6. Containment Buildings I

Ggnera{Anas i 12g 12p l

-unun <m.vm 4,v 4,.

Reactor Cavity Exhaust 150 ISO difr R.C. Pipe Pe etretien5 W -209 CROM Shroud Exhaust 163 17 l

COMANCHE PEAK - UNITS 1 AND 2 3/4 7-25

tac m t to TXX-92292 P 3/4.5 EMERGENCY CORE COOLING SYSTEMS BASES 3/4.5.1 AZe C ~

The OPERABILITY of each Reactor Coolant System (RCS) accumulator ensures that a sufficient volume of t, orated water will be immediately forced into the reactor core through each of the cold legs in the event the RCS pressure f alls below the pressure of the at:umulators. This initial surge of water into the core provides the initial cooling mechanism during large RCS pipe ruptures.

The limits on accumulator volume, boron concentration and pressure ensure _

that the assumptions used for accumulator injection in the safety analysis are met The required indicated accumulator volumes and pressures include a v

1. dpercentmeasurementuncertainty. Theindicatedaccumulatorvolumesofh39$%

g andM1 arebasedontheanalyticallimitsofj61197gallonsand%6597Jgal-lont, re pectively, plus a tank tolerance.

The accumulator power operated isolation valves are considered to be

" operating bypasses" in the context of IEEE Std. 279-1971, which requires that bypasses of a protective function be removed automatically whenever permissive conditions are not met. In addition, as these accumulator isolation valves fail to meet single failure criteria, removal of power to the valves is required by BTP ICSB 18. This is accomplished via key-lock control boarc cut-off switches.

The limits for operation with an accumulator inoperable for any reason except an isolation valve closed minimizes the time exposure of the plant to a LOCA event occurring concurrent with failure of an additional accumulator which may result in unacceptable peak cladding temperatures. If a closed isolation valve cannot be immediately opened, the full capability of one [

accumulator is not available and prompt action is required to place the reactor in a mode where this capability is not required.

3/4.5.2 and 3/4.5.3 ECCS SUBSYSTEMS The OPERABILITY of two independent ECCS subsystems ensures that sufficient emergency core cooling capability will be avaihble in the event of a LOCA assuming the loss of one subsystem through any single failure consideration.

Either subsystem operating in conjunction with the accumulators is capable of supplying sufficient core cooling to limit the peak cladding temperatures within acceptable limits for all postulated break sizes ranging from the double ended break of the largest RCS cold leg pipe downward. In addition, each ECCS subsystem provides long-term core cooling capability in the recirculation mode during the accident recovery period.

With the RCS temperature below 350*F, one OPERABLE ECCS subsystem is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the limited core cooling requirements.

The limitation for a maximum of two charging pumps to be OPERABLE and the requirement to verify one charging pump and all safety injection pumps COMANCHE PEAK - UNITS 1 AND 2 B 3/4 5-1

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Attachment to TXX-92292 MMT Page 7 of 7 3/4.6 CONTAINMENT SYSTEMS BASES 3/4.6.1 PRIMARY CONTAINMENT 3/4.6.1.1 CONTAINMENT INTEGRITY Primary CONTAINMENT INTEGRITY ensures that the release of radioactive materials from the containment atmosphere will be restricted to those leakage paths and associated leak rates assumed in the safety analyses. This restric-tion, in conjunction with the leakage rate limitation, will limit the EXCLUSION AREA BOUNDARY radiation doses to within the dose guideline values of 10 CFR 100 during accident conditions.

3/4.6.1.2 CONTAINMENT LEAKAGE The limitations on containment leakage rates ensure that the total containment leakage volume will not exceed the value assumed in the safety analyses at the peak accident pressure, P,. As an added conservatism, the measured overall integrated leakage rate is further limited to less than or equal to 0.75 L, or 0.75 L g, as applicable, during performance of the periodic test to account for possible degradation of the containment leakage barriers between leakage tests.

For specific system configurations, credit may be taken for a 30-day water seal that will be maintained to prevent containment atmosphere leakage through the penetrations to the environment. The following is a list of the containment isolation valves that meet this system configuration and the Maximum Allowed Leakage Rate (MALR) required to maintain the water seal for 30 days.

MALR -

Valve No. (cc/hr) 2~ Ud A 7#

I- 8809A 77 p 8

4g 7h A - 6'80 't 8 73 CT-142 (4734 JI  ?- EMO g O ^3 CT-145 [4734 )

HV-4776 .[4734 )j HV-4777 (4734y k~ 11 4 The surveillance testing for measuring leanage rates is consistent with the requirements of 10 CFR 50 Appendix J.

3/4.6.1.3 CONTAINMENT AIR LOCKS The limitations on closure and leak rate for the containment air locks are required to meet the restrictions on CONTAINMENT INTEGRITY and containment leak rate. Surveillance testing of the air lock seals provides assurance that the overall air lock leakage will not become excessive due to seal damage during the intervals between air lock leakage tests.

COMANCHE PEAK - UNITS 1 AND 2 B 3/4 6-1 )

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