ML20107K310
| ML20107K310 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  (NPF-03-A-211, NPF-3-A-211) |
| Issue date: | 04/23/1996 |
| From: | Gundrum L NRC (Affiliation Not Assigned) |
| To: | |
| Shared Package | |
| ML20107K312 | List: |
| References | |
| NUDOCS 9604260089 | |
| Download: ML20107K310 (8) | |
Text
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[puog't UNITED STATES l
NUCLEAR REGULATORY COMMISSION E
WASHINGTON, D.C. 2066H001 TOLEDO EDISON COMPANY CENTERIOR SERVICE COMPANY 800 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY DOCKET NO. 50-346 DAVIS-BESSE NUCLEAR POWER STATION. UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 211 License No. NPF-3 1.
The Nuclear Regulatory Comission (the Comission) has found that:
A.
The application for amendment by the Toledo Edison Company, Centerior Service Company, and the Cleveland Electric Illuminating Company (the licensees) dated February 5,1996, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission's rules and regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.
There is reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations; D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
2.
Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.0.(2) of Facility Operating License No. NPF-3 is hereby amended to read as follows:
l 9604260089 960423 PDR ADOCK 05000346 P
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. (2)
Technical Snecifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 211, are hereby incorporated in the license.
The Toledo Edison Company shall operate the facility in accordance with the Technical Specifications.
3.
This license amendment is effective as of its date of issuance and shall be implemented not later than 90 days after issuance.
FOR THE NUCLEAR REGULATORY COMISSION Linda L. Gundrum, Project Manager Project Directorate III-3 Division of Reactor Projects III/IV Office of Nuclear Reactor Regulation
Attachment:
Changes to the Technical Specifications Date of issuance:
April 23, 1996 l
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ATTACHMENT TO LICENSE AMENDMENT NO. 211 FACILITY OPERATING LICENSE NO. NPF-3 DOCKET NO. 50-346 Replace the following pages of the Appendix "A" Technical Specifications with the attached pages. The revised pages are identified by amendment number and contain vertical lines indicating the area of change.
Remove Insert 3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-12a 3/4 3-12a B 3/4 3-1 B 3/4 3-1 B 3/4 3-la B 3/4 3-la
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RNr TABLE 3.3-3 (Continued 1 w
SAFETY FEATURES ACTUATION SYSTEN INSTRUMENTATION NINIMUM TOTAL NO.
UNITS UNITS APPLICABLE FUNCTIONAL UNIT OF UNITS TO TRIP OPERABLE MODES ACTION 3.
MANUAL ACTUATION w
a.
SFAS (except Containment i
Spray and Emergency Sump Recirculation) 2 2
2 1,2,3,4,6****
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b.
2 2
1,2,3,4 12 4.
SEQUENCE LOGIC CHANNELS a.
Sequencer 4
2/ BUS 2/ BUS 1,2,3,4 15#
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b.
Essential Bus Feeder Breaker Trip (90%)
4*****
2/ BUS 2/ BUS 1,2,3,4 15#
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c.
Diesel Generator Start,
.LF Load shed on Essential jM Bus (59%)
4 2/ BUS 2/ BUS 1,2,3,4 15#
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INTERLOCK CHANNELS y'
a.
Decay Heat Isolation Valve 1
1 1
1,2,3 13#
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b.
Pressurizer Heaters 2
2 2
3******
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TABLE 3.3-3 (Continued)
TABLE NOTATION Trip function may be bypassed in this MODE with RCS pressure below 1
1800 psig. Bypass shall be automatically removed when RCS i
pressure exceeds 1800 psig.
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Trip function may be bypassed in this MODE with RCS pressure below 600 psig. Bypass shall be automatically removed when RCS pressure j
exceeds 600 psig.
l DELETED l
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This instrumentation, or the containment purge and exhaust system i
noble gas monitor (with the containment purge and exhaust system in operation), must be OPERABLE during CORE ALTERATIONS or i
mnvement of irradiated fuel within containment to meet the l
requirements of Technical Specification 3.9.4.
When using the j
containment purge and exhaust system noble gas monitor, SFAS is not required to be OPERABLE in MODE 6.
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All functional units may be bypassed for up to one minute when j
starting each Reactor Coolant Pump or Circulating Water Pump.
i When either Decay Heat Isolation Valve is open.
i The provisions of Specification 3.0.4 are not applicable.
ACTION STATEMENTS ACTION 10 - With the number of OPERABLE functional units one less than the l
Total Number of Units, STARTUP and/or POWER OPERATION may proceed provided both of the following conditions are satisfied:
1' a.
The inoperable functional unit is placed in the tripped
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condition within one hour.
j b.
The Minimus Units OPERABLE requirement is met; however, one l
additional functional unit may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> j
for surveillance testing per Specification 4.3.2.1.1.
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ACTION 11 - With any component in the Output Logic inoperable, trip the associated components within one hour 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 l
following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
DAVIS-BESSE, UNIT 1 3/4 3-12 Amendment No. 28, 27, 52, 102, j
-M5,--150, ISS, 211 i
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TABLE 3.3-3 (Continued) i ACTION STATEMENTS ACTION 12 - With the number of OPERABLE Units one less than the Total Number of Units, restore the inoperable functional unit to OPERABLE i
status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STAN08Y 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 />, i
ACTION 13 - a.
With less than the Minimum Units OPERABLE and reactor coolant pressure 1438 psig, both Decay Heat Isolation Valves (DH11 and DH12) shall be verified closed.
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b.
With less than the Minimum Units OPERABLE and reactor j
coolant pressure < 438 psig operation may continue; however, i
the functional unit shall be OPERABLE prior to increasing i
reactor coolant pressure above 438 psig.
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ACTION 14 - With less than the Minimum Units OPERABLE and reactor coolant pressure < 438 psig, operation may continue; however, the j
functional unit shall be OPERABLE prior to increasing reactor coolant pressure above 438 psig, or the inoperable functional unit j
shall be placed in the tripped state.
ACTION 15 - a.
With the number of OPERABLE units one less than the Minimum j
Units Operable per Bus, place the inoperable unit in the tripped condition within one hour.
For functional unit 4.a the sequencer shall be placed in the tripped condition by i
physical removal of the sequencer module. The inoperable functional unit may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for i
surveillance testing per Specification 4.3.2.1.1.
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b.
With the number of OPERABLE units two less than the Minimum i
l Units Operable per Bus, declare inoperable the Emergency Diesel Generator associated with the functicnal units not j
meeting the required minimum units OPERABLE and take the ACTION required of Specification 3.8.1.1.
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i DAVIS-BESSE, UNIT 1 3/4 3-12a Amendment No. 20, 52, 102, j
-+3h 211 4
3/4.3 INSTRUMENTATION 1
BASES 3/4.3.1 and 3/4.3.2 REACTOR PROTECTION SYSTEM AND SAFETY SYSTEM INSTRUMENTATION The OPERABILITY of the RPS, SFAS and SFRCS instrumentation systems ensure that
- 1) the associated action and/or trip will be initiated when the parameter monitored by each channel or combination thereof exceeds its setpoint, 2) the specified coincidence logic is maintained, 3) sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance, and 4) sufficient system functional capability is available for RPS, SFAS and SFRCS purposes from diverse parameters.
The OPERABILITY of these systems is required to provide the overall reliability, redundance and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions.
The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses.
The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards.
The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.
The measurement of response time at the specified frequencies provides assurance that the RPS, SFAS, and SFRCS action function associated with each channel is completed within the time limit assumed in the safety analyses.
No credit was taken in the analyses for those channels with response times indicated as not applicable.
Response time may be demonstrated by any series of sequential, overlapping or total channel test measurements provided that such tests demonstrate the total channel response time as defined.
Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test measurements or 2) utilizing replacement sensors with certified response times.
The actuation logic for Functional Units 4.a., 4.b., and 4.c. of Table 3.3-3, Safety Features Actuation System Instrumentation, is designed to provide protection and actuation of a single train of safety features equipment, essential bus or emergency diesel generator. Collectively, Functional Units 4.a., 4.b., and 4.c. function to detect a degraded voltage condition on either of the two 4160 volt essential buses, shed connected loads, disconnect the affected bus (es) from the offsite power source and start the associated emergency diesel generator.
In addition, if an SFAS actuation signal is present under these conditions, the sequencer channels for the two SFAS channels which actuate the train of safety features equipment powered by the affected bus will automatically sequence these loads onto the bus to prevent overloading of the emergency diesel generator.
Functional Unit 4.a. has a DAVIS-BESSE, UNIT 1 8 3/4 3-1 Amendment No. ??, !?5, l
(Next page is 8 3/4 3-la) 49&; 211
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i 3/4.3 INSTRUMENTATION
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BASES l
3/4.3.1 and 3/4.3.2 REACTOR PROTECTION SYSTEM AND SAFETY SYSTEM INSTRUMENTATION (Continued) total of four units, one associated with each SFAS channel (i.e., two for each i
essential bus).
Functional Units 4.b. and 4.c. each have a total of four i
units, (two associated with each essential bus); each unit consisting of two undervoltage relays and an auxiliary relay.
An SFRCS channel consists of 1) the sensing device (s), 2) associated logic and j
output relays (including Isolation of Main Feedwater Non Essential Valves and Turbine Trip), and 3) power sources.
The SFRCS response time for the turbine stop valve closure is based on the 4
combined response times of main steam line low pressure sensors, logic cabinet delay for main steam line low pressure signals and closure time of the turbine stop valves. This SFRCS response time ensures that the auxiliary feedwater to d
the unaffected steam generator will not be isolated due to a SFRCS low j
pressure trip during a main steam line break accident.
i Safety-grade anticipatory reactor trip is initiated by a turbine trip (above i
45 percent of RATED THERMAL POWER) or trip of both main feedwater pump turbines. This anticipatory trip will operate in advance of the reactor i
coolant system high pressure reactor trip to reduce the peak reactor coolant system pressure and thus reduce challenges to the pilot operated relief valve.
l This anticipatory reactor trip system was installed to satisfy Item II.K.2.10 i
of NUREG-0737. The justification for the ARTS turbine trip aming level of 45% is given in BAW-1893, October, 1985.
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i DAVIS-BESSE, UNIT 1 B 3/4 3-la Amendment No. 73, 125, 128, 135, 211 i
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