ML20246P625
| ML20246P625 | |
| Person / Time | |
|---|---|
| Site: | Cooper  |
| Issue date: | 08/31/1989 |
| From: | NEBRASKA PUBLIC POWER DISTRICT |
| To: | |
| Shared Package | |
| ML20246P623 | List: |
| References | |
| NUDOCS 8909110190 | |
| Download: ML20246P625 (8) | |
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.[3.b RA9b Cont'd) m. . _ _ - . _ _ . . _
(B. , Core and Containment Cooline Systems Initiation and Control 33
-- The. instrumentation which initiates Core Standby Cooling System (CSCS)1 acti;n ir-arranged:in'a.du'la bus system. As for other vital instrumentation arranged
.in this: fashion,1 the' Specification preserves the' effectiveness of-the system-even during periods when maintenance:or testing is being performed. An
-exception to'this is:when logic functional testing is being performed.
CORE' SPRAY e No Basis-1.PCI MODE =No Basis.
~
HPC1 The'HPCI high flow and. temperature instrumentation are provided to detect a
- break _ in the HPCI.' steam piping including the RHR Condensing Mode Steam. Tripping
{ of. this instrumentation results in actuation of HPCI isolation valves. Tripping logic for the high flow is a 1 out of 2 logic.
Temperature is reonitored et twelve (12) locations with four (4) temperature sensors at each location. Two (2) sensors at each location are. powered by.
"A". direct. current control bus and two.(2) by "B" direct current control bus.
-Each pair,of sensors, e.g., "A" or "B", at each location are physically separated and the tripping of either "A" or "B" bus sensor will' actuate HPCI isolation valves.
The. trip settings of s 300% of design flow for high flow and s 200*F for high
.. temperature are such that. core uncovery is prevented and fission product
' release is within limits.
RCIC" The RCIC high flow and temperature instrumentation are arranged the same as that for.the HPCI, ~ The trip setting of 5 300% for high flow and s 200'F
-for temperature-are based on the same criteria as the HPCI.
1 ADS l
The' effective emergency core cooling for small pipe breaks, the HPCI system, must function since reactor pressure does not decrease rapid enough to allow either core spray or LPCI to operate-in time. The automatic pressure relief.
function is provided as'a. backup to.the HPCI in the event the HPCI does not operate. .The' arrangement of the tripping contacts is such as to provide this function when necessary and minimize spurious operation. The trip settings
.given'in the" specification are adequate to assure the above criteria are met.
The specification preserves the effectiveness of the system during periods of maintenance, testing, or calibration, and also minimizes the risk of inadver-tent operation; i.e., only one instrument channel out of service.
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,jf ' 1.TMYTING CONDITI0IT FOR OPERTATON SURVETf1ANCE RRotfTREMFMT' h M7. A ' (cont' d. ) 4.7.A (cont'd) k
- 6. ' Low-Low' Set ftelief FunctioD 6. Low-Low Set Reliaf Function ge ta. The low-low set function of the a. The low-low set safety / relief. !
safety-relief valves shall be. . valves shall be. tested and operable when there is irradiated calibrated as specified in fuel in"the reactor vessel and the -Table 4.2.B.
reactor coolant temperature is k 212*F,
- .except.as:specified in 3.7.A.6.a.1 and 2 below.-
3: . . . . .
.1. With the: low-low' set function of one i safety / relief valve'(S/RV) inoperable, l
. restore the ineperable LLS S/RV.to !
. DPEF ABLE within 14 days or be in the HOT JTANDBY mode within-the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-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 />.
2;- With the low-low set function of both S/RVs inoperable, be ir. at least HOT 1
, STANDBY within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD l SHUTDOWN within the.next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. !
- b. The pressure switches which control )
the' low-low' set safety / relief valves l shall have the'following settings.
.I NBI-PS-51A Open Low Valve i 1015 i 20 psig (Increasing) {
l
- NBI-PS-51B Close Low Valve' ,
875 20 psig (Decreasing) '
~NBI-PS-51C Open High Valve 1025 1 20 psig (Increasing) .
j B. Standby Gas Treatment System !
NBI-PS-51D Close High Valve ]
875 i 20 psig (Decreasing) 1. At least once per operating cycle the following conditions shall be ,
.B. Standby Gas Treatment System demonstrated. ~l
- 1. Except as.specified in 3.7.B.3 below,
- a. Pressure drop ceross the combined i HEPA filters and charcoal adsorber
.both standby gas treatment systems banks is less than 6 inches of ;
shall be operable at all times when water at the system design flow rate. >
secondary containment integrity is l required. b. Inlet heater input is cable of I reducing R.H. from 100 to 70% R.H. I 2,.'s;.The results of the in-place cold DOP 2.a. The tests and sample analysis of and halogenated hydrocarbon leak tests Specification 3.7.B.2 shall be at s design flow-(1780 CFM) and at a performed at least once per year
. reactor. building pressure 5 .25" Ug for standby service or after every on HEPA filters and charcoal adsorber 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of system operation and i
banks respectively shall show 299% following significant painting, fire DOP removal.and a99% halogenated
&&M ase 6 dlatim hydrocarbon removal. zone communicating with the system.
-165-
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'T SURVEII.TANCE REOUTREMENT
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L1 3.7'.B L (cont' d) 4.7.B (cont'd) g0 b. Cold DOP testing shall be performed
- b. The results of laboratory carbon sample analysis shall show E99% after each complete.or partial radioactive methyl iodide removal replacement of the HEPA filter i
with-inlet conditions'of: velocity bank or after'any structural 1
242 FPM, 21.'75 mg/ms inlet methyl maintenance on thb system housing. ,
' iodide concentration, 270% R.H.
and $30*C.- c. Halogenated' hydrocarbon testing.
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shall be performed after each
- c. Each fan shall be shown to provide complete or partial replacement.
- 1780 CMF 110%. of the charcoal edsorber bank or-after any structural maintenance
- 3. -F om and after the date that one on the system housing, standby gas treatment system is made
! 'or found to be inoperable-for any d. Each system shall be operated L reason, reactor operation is with the heaters on at least permissible only during the 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> every month, succeeding seven-days unless such e. Test sealing of gaskets for housing system is sooner made operable, doors downstream of the HEPA provided that-during such seven filters and charcoal adsorbers days all active components of the shall be performed at, and in other standby gas treatment system, confromance with, each test and its associated diesel generator' performed for compliance with p shall be operable.
Specification 4.7.B.2.a and Specificati n 3.7.B.2.a.
' Fuel handling requirements are specified in Specification.3.10.E.
- 3. System drains where present shall be inspected quarterly for adequate
- 4. 'If these conditions cannot be met, water level in loop-seals,
- procedures shall be initiated immediately-to establish reactor 4.a. At least once per operating cycle conditions for which the standby automatic initiation of each branch of gas treatment system is not de standh gas treatment system shall required.
be demonstrated.
- b. At least once per operating cycle manual operability of the bypass valve for filter cooling shall l.
be demonstrated.
- c. When one standby gas treatment system bectames inoperable the other standby gas treatment system shall be demonstrated to be operable immediately and daily thereafter.
A demonstration of diesel generator operability is not required by this specification.
C. Secondary Containment C. Secondary Containment
- 1. Secondary containment integrity 1. Secondary containment surveillance shall be maintained during all shall be performed as indicated below:
modes of plant operation except when'all of the following conditions are met.
-165a-
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s 3.7;A & 4.7.A BASES (cont'd)
The primary containment is normally slightly pressurized during periods of reactor operation. Nitrogen used for inerting could leak out of the containment but air could no leak in to increase oxygen concentration. Once the containment is filled with nitrogen to the required concentration, no monitoring of oxygen concentration is necessary. However, at least twice a week the oxygen concentration will be determined as added assurance.
The 500 gallon conservative limit on the nitrogen storage tank assures that adequate time is available to get the tank refilled assuming normal plant operation. The estimated maximum makeup rate is 1500 SCFD which would require about 160 gallons for a 10 day makeup requirement. The normal leak rate should be about 200 SCFD.
3.7.A.6 6 4.7.A.6 LOW-LOW SET REL1EF FUNCTION The low-low set relief logic is an automatic safety relief valve (SRV) control system designed to mitigate the postulated thrust load concern of subsequent actuations of SRV's during certain transients (such as inadvertent MSIV closure) and small and intermediate break loss-of-coolant accident (LOCA) events. The setpoints used in Section 3.7.A.6.b are based upon a minimum blowdown range to provide adequate time between valve actuations to allow the SRV discharge line high water leg to clear, j coupled with consideration of instrument inaccuracy and the main steam isolation valve isolation setpoint.
The 'as-found setpoint for NBI-PS-51A, the pressure switch controlling the opening of !
RV-71D, must be s 1040 psig. The as-found closing setpoint for NB1-PS-51B must be at least 90 psig less than 51A, and must be 2 850 psig. The as-found setpoint for NBI-PS-51C, pressure switch contro111ng'the opening of RV-71F must be s 1050 psig. ,
The as-found closing setpoint for NEI-PS-51D must be at least 90 psig below 51C, and i must be h 850 psig. This ensures that the anlaytical upper limit for the opening ;
2 setpoint (1050 psig), the analytical lower limit on the closing setpoint (850 psig) and the analytical limit on the blowdown range (2, 90 psig) for the Low-Low Set Relief Function are not exceeded. The upper limit is set such that, if both the lowest sec non-LLS S/RV and the highest set of the two LLS S/RVs drift 25 psig in the worst case directions, the LLS S/RVs will still control subsequent S/RV actuations.. Likewise, the lower limit is set to ensure tre LLS S/RV closing setpoint remains above the MSIV low pressure trip. The 90 psig blowdown provides adequate energy release from the j vessel to ensure time for the water leg to clear between subsequent S/RV actuations.
3.7.B & 3.7.C STANDBY GAS TREATMENT SYSTEM AND SECONDARY CONTAINMENT ,
i The secondary containment is designed to minimize any ground level release of radioactive materials which might result from a serious accident. The reactor building provides secondary containment during reactor operation when the drywell is sealed and in service. The reactor building provides primary containment when the reactor is shut down and the drywell is open, as during refueling. Because the secondary containment is an integral part of the complete containment system, secondary containment is required at all times that primary containment is required i j .as well as during refueling. Secondary containment may be broken for short periods i
of time to allow access to the reactor building roof to perform necessary inspections !
and maintenance.
The standby gas treatment system is designed to filter and exhaust the reactor i building atmosphere to the stack during secondary containment isolation conditions. j Both standby gas treatment system fans are designed to automatically start upon containment isolation and to maintain the reactor building pressure to the design negative pressure so that all leakage should be in-leakage. Should one system fail to start, the redundant system is designed to start automatically. Each of the two fans has 100 percent capacity.
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