ML20095G514

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Proposed Tech Specs 3.3.1.1, RPS Instrumentation & TS 3.3.6.1, Primary Containment Dwl Isolation Instrumentation to Eliminate Periodic Response Time Testing of Analog Trip Modules
ML20095G514
Person / Time
Site: Clinton Constellation icon.png
Issue date: 12/14/1995
From:
ILLINOIS POWER CO.
To:
Shared Package
ML20095G503 List:
References
NUDOCS 9512210075
Download: ML20095G514 (10)
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Text

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4 . Attachment 3 to U-602520 LS-95-007 Page1of5 i

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Attachment 3 to U-602520 LS-95-007 f ,

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RPS. Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.16 Verify Turbine Stop Valve Closure and 18 months Turbine Control Valve Fast Closure Trip 011 Pressure-Low Functions are not bypassed when THERMAL POWER is 2 40% RTP.

l SR 3.3.1.1.17 ------------------NOTES------------------

1. Neutron detectors are exc1'uded.
2. For Functions 3, 4, and 5 in Table j i

f}And analbh{} 3.3.1.1-1, the channel sensor are Liv 4p rnedules excluded.

2_

3. The STAGGERED TEST BASIS Frequency for each Function shall be determined j on a per channel basis.

Verify the RPS RESPONSE TIME is within 18 months on a limits. STAGGERED TEST BASIS 1

CLINTON 3.3-6 Amendment No. AE,98' l

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' Attachment $"tio U 4@2520~' ' ,

' LS-95-007 l

/do t b nges. 7 (ov.Ye[ Page 3 of 5 Q>< conHo v @ M ly .

, RPS Instrumentation 3.3.1.1 Table 3.3.1.1 1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONo!TIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWASLE FUNCTION CON 0!TIONS FUNCT10N ACTION 0.1 REQUIREMENTS VALUE

3. Reactor vesset steam Dome 1,2 4 N st 3.3.1.1.1 s 1080 pelg Pressure - Nigh SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15 st 3.3.1.1.17
4. Reactor Vessel Water . 1,2 4 H SR 3.3.1.1.1
  • 8.3 Inches Level-Low, Level 3 st 3.3.1.1.9 st 3.3.1.1.10 st 3.3.1.1.13 st 3.3.1.1.15 st 3.3.1.1.17
5. Reactor vessel Water a 25 % RTP 4 F st 3.3.1.1.1 s 52.6 Inches Level-Nigh, Levet 8 SR 3.3.1.1.9 st 3.3.1.1.10 st 3.3.1.1.13 st 3.3.1.1.15 st 3.3.1.1.17
6. Main steam Isolation 1 4 G st 3.3.1.1.9 s 12% closed Valve - Closure SR 3.3.1.1.13 st 3.3.1.1.15 st 3.3.1.1.17
7. Crywell Pressure-Migh 1,2 4 H SR 3.3.1.1.1 s 1.88 pois sR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15
8. scram Olscharge Volune Water Levet -High
e. Transmitter 1,2 4 N SR 3.3.1.1.1 s 40 1/4 inches SR 3.3.1.1.9 for 1C11-SR 3.3.1.1.10 N601A,B and SR 3.3.1.1.13 s 39 3/16 SR 3.3.1.1.15 inches for 1C11 N601C,0 5(a) 4 I st 3.3.1.1.1 s 40 1/4 inches SR 3.3.1.1.9 for 1C11-SR 3.3.1.1.10 N601A,s and st 3.3.1.1.13 5 39 3/16 st 3.3.1.1.15 inches for 1C11 N601C,0 (continued)

(a) With any control rod withdrawn from a core cell containing one or more fuel asseebtles.

CLINTON 3.3-8 Amendment No. 95

ageactuments N ^ ~-

LS-95-007 Page 4 of 5 Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

.1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment and Drywell Isolation Function.

2. Wh'en a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.1.3 Calibrate the analog trip module. 92 days SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. 92 days SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. 18 months SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. 18 months SR 3.3.6.1.7 ------------------NOTES------------------

1. Channel sensoryare excluded, d *S 2. The STAGGERED TEST BASIS Frequency LM P rnebles for each Function shall be determined on a per channel basis.

Verify the ISOLATION SYSTEM RESPONSE TIME 18 months on a for the main steam isolation valves is STAGGERED TEST within limits. BASIS CLINTON 3.3-54 Amendment No. Ah g

Attachment 3 to U-602520 LS-95-007 No Chd & PN'N* #8" $ $

& nv.h only. Pricary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 1 of 7)

Prleary Contalment and OrWett Iso 1etion instrunentatIon APPLICARLE CONO1)10NS MODES OR REQUIRED REFERENCE 0 ,

OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CON 0lfl0Ns FUNCTION ACTION F.1 REQUIREMENTS VALUE

1. Main steam Line Isolation
a. Reactor vessel Water 1,2,3 4 G SR 3.3.6.1.1 t 147.7 inches Level -Low Low Low, sR 3.3.6.1.2 Levet 1 $R 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7
b. Main steam Line 1 4 H SR 3.3.6.1.1 k 837 psig Pressure - Low st 3.3.6.1.2 SR 3.3.6.1.3 sR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7
c. Main steam Line 1,2,3 4 G sa 3.3.6.1.1 s 178 psid F tou - NIgh sa 3.3.6.1.2 st 3.3.6.1.3 st 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7
d. Condenser Vacuus-Low 1,2(a) , 4 G SR 3.3.6.1.1 t 7.6 inches SR 3.3.6.1.2 Ng vacuun 3(*) SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6
e. Main steam Tumet 1,2,3 4 G SR 3.3.6.1.1 5 171'T Towperature - Nish SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6
f. Main steam Line Turbine 1,2,3 4 G st 3.3.6.1.1 Modules 1 4 sullding SR 3.3.6.1.2 s 142'F, Temperature - Nigh SR 3.3.6.1.5 Modute 5 SR 3.3.6.1.6 s 150*F
g. Manual Initiation 1,2,3 s 4 J SR 3.3.6.1.6 NA (continued)

(a) With any turbine stop valve not closed.

CLINTON 3.3-55 Amendment No. 95

Attachment 4 to U-602520 LS-95-007 Page1of5 Technical Specification Bases Changes l

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  • [@$*I!1sNumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3,1.1.16 REQUIREMENTS This SR ensures that scrams initiated from the Turbine Stop (continued) Valve Closure and Turbine Control Valve Fast Closure, Trip 011 Pressure-Low Functions will not be inadvertently i bypassed when THERMAL POWER is t 40% RTP. This involves I

calibration of the bypass channels. Adequate margins for i I

the instrument setpoint methodology are incorporated into I the actual setpoint.

If any bypass channel setpoint is nonconservative such that the Functions are bypassed at a 40% RTP (e.g., due to open l main steam line drain (s), main turbine bypass valve (s) or other reasons), then the affected Turbine Stop Valve closure and Turbine Control Valve Fast Closure, Trip Oil Pressure-Low Functions are con'sidered inoperable.

Alternatively, the bypass channel can be placed in the conservative condition (nonbypass). If placed in the nonbypass condition, this SR is met and the channel is considered OPERABLE.

The Frequency of 18. months is based on engineering judgment and reliability of the components.

SR 3.3.1.1.17 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. The RPS RESPONSE TIME acceptance criteria are included in plant Surveillance procedures.

As noted, neutron detectors are excluded from RPS RESPONSE TlHE testing because the principles of detector operation virtually ensure an instantaneous response time. In MO addition, for Functions 3, 4, and 5, the associated sensors ll w p w M .$c4 re not required to be response time tested. For these Functions, r ng for the remaining channel componen , ir.cluding the ^"s v is required. This allowance ll is suppor e e cu 10.

RPS RESPONSE TIME tests are conducted on an 18 month STAGGERED TEST BASIS. Note 3 of SR 3.3.1.1.17 requires STAGGERED TEST BASIS Frequency for each Function to be (continued)

CLINTON B 3.3-29 Revision No. /

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-, _ _ Attachment 4 to U'-6dE520' ^

NO Chond*S 7##### I*'e"5oIs OrCoy)MOVh CG .

RPS Instrumentation B 3.3.1.1 f

BASES SURVEILLANCE SR 3.3.1.1.17 (continued)

REQUIREMENTS determined separately based on the four channels as specified in Table 3.3.1.1-1. This Frequency is based on the logic interrelationships of the various channels required to produce an RPS scram signal. l Therefore, staggered testing results in response time i

. verification of these devices eve'ry 18 months. This  !

Frequency 'is consistent With the typical industry refueling

' cycle and is based upon plant operating experience, which-shows that random failures of instrumentation components causing serious time degradation, but not channel failure, are infrequent.  !

l REFERENCES 1. USAR, Section 7.2. ,

2. USAR, Section 5.2.2.
3. USAR, Section 6.3.3.
4. USAR, Chapter 15.
5. USAR, Section 15.4.1.2.
6. NED0-23842, " Continuous Control Rod Withdrawal in the

. Startup Range," April 18, 1978.

7. USAR, Section 15.4.9.
8. Letter, P. Check (NRC) to G. Lainas (NRC), "BWR Scram Discharge System Safety Evaluation," December 1,1980, as attached to NRC Generic Letter dated December 9, 1980.
9. NED0-30851-P-A, " Technical Specification Improvement Analyses for BWR Reactor Protection System,"

Harch 1988.

10. NED0-32291-A, " System Analyses for Elimination of Selected Response Time Testing Requirements," January 1994.

CLINTON B 3.3-30 Revision No. 1

LS-95-007 No c.hanges.7caddej b CorWiOV h PrimaryContainmentandDrywellIsolat$ofiks?fubentation  !

8 3.3.6.1 On%.

l BASES SR 3.3.6.1.4 and SR 3.3.6.1,5 (continued)

SURVEILLANCE REQUIREMENTS responds to the measured parameter within the necessary range and accuracy. CHANNEL CAllBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.

The Frequency of SR 3.3.6.1.4 and SR 3.3.6.1.6 is based on the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.6.1.6 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific i channel. The system functional testing performed on PCIVs l l

in LC0 3.6.1.3 and on drywell isolation valves in LC0 l 3.6.5.3 overlaps this Surveillance to provide complete  !

testing of the assumed safety function. The 18 month l i

Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 18 month Frequency.

The Self Test Syrtem may be utilized to perform this testing for those components that it is designed to monitor. Those

! portions of the solid-state logic not monitored by the Self' Test System may be tested at the frequency recommended by l the manufacturer, rather than at the specified 18-month l

Frequency. The frequencies recommended by the manufacturer are based on mean time between failure analysis for the components in the associated circuits.

SR 3.3.6.1.7 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. Testing is performed only on channels l where the assumed response time does not correspond to the l

I diesel generator (DG) start time. For channels assumed to respond within the DG start time, sufficient margin exists I in the 12 second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response without a specific measurement test. The (continued)

CLINTON B 3.3-172 Revision No. 1-1 f

LS-95-007 Page 5 of 5 Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.7 (continued) l REQUIREMENTS instrument response times'must be added to the MSIV closure ,

I times to obtain the ISOLATION SYSTEM RESPONSE TIME.

ISOLATION SYSTEM RESPONSE TIME acceptance criteria are included in applicable plant procedures, and aruloj As noted, the associated sensorsAare not required to be \l l Wip rreddes response time tested. Respon ti s the l remaining channel component ,--ir.c.ud.n- th AT."pi is 0 l required. This is supporte e erence 7-Note 2 to SR 3.3.6.1.7 requires the STAGGERED TEST BASIS Frequency for each Function to be determined seperately based on the number of channels as specified on Table 3.3.6.1-1. This Frequency is based on the logic interrelationships of the various channels required to produce an isolation signal, j ISOLATION SYSTEM RESPONSE TIME tests are conducted on an 18 month STAGGERED TEST BASIS. This Frequency is consistent .

with the typical industry refueling cycle and is based upon I plant operating experience that shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent.

REFERENCES 1. USAR, Section 6.2.

2. USAR, Chapter 15.
3. NED0-31466, " Technical Specification Screening Criteria Application and Risk Assessment,"

November 1987.

4. USAR, Section 9.3.5.
5. NEDC-31677-P-A, " Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation,"

June 1989.

6. NEDC-30851-P-A, Supplement 2, " Technical Specifications Improvement Analysis for BWR Isolation Instrumentation Common to RPS and ECCS Instrumentation," Harch 1989.

(continued)

CLINTON B 3.3-173 RevisionNo./O

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