ML20004C977
| ML20004C977 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 06/01/1981 |
| From: | Stolz J Office of Nuclear Reactor Regulation |
| To: | Cleveland Electric Illuminating Co, Toledo Edison Co |
| Shared Package | |
| ML20004C978 | List: |
| References | |
| NPF-03-A-040 NUDOCS 8106080116 | |
| Download: ML20004C977 (13) | |
Text
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4 UNITED STATES e
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4 NUCLEAR REGULATORY COMMISSION f
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THE TOLEDO EDIS0N COMPANY AND THE CLEVELAND ELECTRIC ILLUMINATING COMPANY DOCKET NO. 50-346 DAVIS-BESSE NUCLEAR POWER STATION, UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No, 40 License No. NPF-3 1.
The Nuclear Regulatory Comission (the Comission) has found that:
The application for amendment by The Toledo Edison Company)and A,
The Cleveland Electric Illuminating Company (the licensees dated February 24, 1981, complies with the standards aad requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations ' set forth in 10 CFR Chapter I; B.
The facility will operate in confonnity with the application, the provisions of the Act, and the rules and regulations of the Comission; 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 comon defanse 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 Comission's regulations and all applicable requirements have been satisfied.
8106080 %
. 2.
Accordingly, Facility Operating License No. NPF-3 is hereby amended as indicated below and by changes to the Technical Specifications as indicated in the attachment to this license amendment:
-Revise paragraph 2.C.(2) to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendme7t No. 40, 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 the date of its issuance.
FOR THE NUCLEAR REGULATORY COMMISSION 7
fjr F. Stolz, Chief s
ating Reacters Branch #4 I
ision of Licensing
Attachment:
Changes to the Technical Specifications Date of Issuance: June 1,1981 i
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ATTACHMENT TO LICENSE AMENDMENT NO. 40 FACILITY U.'ERATING LICENSE NO. NPF-3 DOCKET NO. 50-346 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages as indicated. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change. The corresponding overleaf pages are also provided to maintain document completeness.
Pages 3/4 3-10 3/4 3-20 3/4 3-21 3/4 5-4 3/4 5-5 I
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. INSTRUMENTATION _
3/4.3.2 SAFETY SYSTEM INSTRUMENTATIOE SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2.1 The Safety Features Actuation System (SFAS) functional units shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of T6ble 3.3-4 and with RESPONSE TIMES as shown in Table 3.3-5.
APPLICABILITY: As shown in Table 3.3-3..
ACTION:
With a SFAS functional unit trip setpoint less conservative a.
than the vrlue shown in the Allowabie Values column of Table 3.3-4, declare the functional unit inoperable and apply the applicable ACT 0N requirement of Table 3.3-3, until the func-tional unit is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint value.
b.
With a SFAS functional unit inoperable, take the action shown in Table 3.3-3.
SURVEILLANCE REQUIREMENTS 4.3.2.1.1 Each SFAS functional unit shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST during the MODES and at the frequencies shewn in Table 4.3-2.
- 4. 3. 2.1. 2 The Icgic for the bypasses shall be demonstrated OPERABLE during the at power CHANNEL FUNCTIONAL TEST of functional units affected by bypass operation. The total byoass function shall be demonstrated OPERABLE at least once per 18 months during CHAhNEL CALIBRATION testing of each functional unit affected by bypass operation.
4.3.2.1.3 The SAFETY FEATURES RESPONSE TIME of each SFAS function shril be demonstrated to be within the limit at least once per 18 months.
Each test shall include at least one functional unit per function such that all functional units are tested at least once every N times 18 months where N is the total number of redundant functional units in a specific SFAS function as shown in the " Total No. of Units" Column of Table 3.3-3.
DAVIS-BESSE. UNIT 1 3/4 3-9 e
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INSTRUMENT STRINGS a.
Containment Radiation -
High 4-2 3
1,2,3,4,6****
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b.
Containment Pressure -
liigh 4
2 3
1, 2, 3 9#
c.
Containment Pressure -
liigh-High 4~
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RCS Pressure - Low 4
2 3
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e.
RCS Pressure - Low-Low 4
2 3
1, 2, 3**
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DWST Level - Low-Low 4
2 3
1,2,3 9#
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OUTPUT LOGIC ii; a.
Incident level #1:
Containment Isolation 2
1 2
1,2,3,4,6****
10 b.
Incident Level #2:
liigh Pressure Injection and Starting Diesel y
Generators 2
1 2
1,2,3,4 10 g.
c.
Incident Level #3:
g Low Pressure Injection 2
1 2
1,2,3,4 10 1
g d.
Incident Level #4:
1 2
1,2,3,4 10 g
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Incident Level #5:
Containment Sump
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1 2
1, 2, 3, 4 10 l
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TABLE 3.3-5 (Continued)
SAFETY FEATURES SYSTEM RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 4.
RCS Pressure-Low (continued) 1.
Containment Isolation Valves 1.
Vacuum Relief
< 30*
7 25*
2.
Normal Sump 3.
RCS Letdown Delay Coil Outlet 7 30*
7 30*
4.
RCS Letdown High Temperature 5.
Pressurizer Sample 745*
6.
Service Water to Cooling Water 7 45*
7 15*
7.
Vent Header 7 15*
8.
Drain Tank 7 15*
9.
Core Flood Tank Vent 10.
Core Flood Tank Fill 7 15*
11.
Steam Generator Sample 7 15*
7 17*
12.
Atmospheric Vent 13.
Quench Tank
-7 15*
14.
Emergency Sump NA*
15.
RCP Seal Return
< 45*
7 15*
16.
Air Systems 7 15*
17.
N, System 7 35*
18.
Quench Tank Sample 19.
Main Steam Warmup Drain 7 15*
7 30*
20.
Makeup 21.
RCP Seal Inlet 7'17*
22.
Core Flood Tank Sample 7 15*
23.
RCP Standpipe Demin Water Supply 7 15*
Containment H Dilution Inlet 7 75*
24.
Containment Hf Dilution Outlet 3[ 75*
25.
j.
BWST Outlet Valves NA*
5.
RCS Pressure--Low-Low t
a.
Low Pressure Injection
< 30*
1.
Decay Heat Pumps 2.
Low Pressure Injection Valves 7 NA*
7 NA*
3.
Decay Heat Pump Suction Valves 4.
Decay Heat Cooler Outlet Valves 7 MA*
5.
Decay Heat Cooler Bypass Valves
][ NA*
b.
Component Cooling Isolation Valves 1.
Auxiliary Equipment Inlet
< 90*
2.
Inlet to Air Compressor 7 90*
3.
Component Cooling from Decay Heat Cooler
][ NA*
DAVIS-BESSE, UNIT 1 3/4 3-19
TABLE 3.3-5 (Continued)
. SAFETY FEATURES SYSTEM RESPONSE TIMES INITIATING SIGNAL AND~ FUNCTION RESPONSE TIME IN SECONDS 6.
Containment Radiation - High a.
Emergency Vent Fans
< 25*
b.
ECCS Room
< 75*
2.
Emergency Ventilation 7 75*
3.
Containment Air Sample 7 30*
4.
Containment Purge 7 15*
5.
Penetration Room Purge 75*
c.
< 10
- TABLE NOTATION Diesel generator starting and sequence loading delays included when applicable. ' Response time 'liinit includes movement of valves and attainment'of pump or blower discharge pressure.
DMIS-BESSE, UNil 1 3/4 3-20 Amendment No. 40 e
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- 1 TABLE 4.3-2 SAFETY FEAT 11RES ACTIIAil0N SYSIEM INSTRUME_NTATl0N SilRVEILLANCE Rg ulREMrtITS i
CilANNIL MODES IN WHICil CilANNEL CilANNFL FUNLil0NAL SURVEILLANCE FUNCTIONAL LMIlT Clll C,K__
CALIRRATION, TLSi REQUIRED 5.
INTERt0CK CHAIINELS Y
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a.
Decay Heat Isolation Valve 5
R 1, L 3, 4, 5 b.
Pressurizer Heater S
R 3.4.5
' **See Specification 4.5.2.d.1 TA8tE IIOTATI0ft N
e (1) Manual actuatton switches shall be tested at least once per 18 months.during shutdown. All other circuitry associated with manual safeguards actuation shall receive a CHANNEL FUNCil0NAL r+
g TEST at least once per 31 days.
k (2) The CitAIINEL FUNCTIONAL TEST shall include eneretsing the transmitter by applying either vacuum or 7
pressure to the appropriate side of the transmitter. The provisions of Section 3.0.3 are not applicable for the.first test of each channel following the first refueling cotage.
i The surveillance requirements of Section 4.9.4 apply during core alteraticas or movement of m
irradiated fuel within the containment.
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EMERGENCY CDRE COOLING SYSTEw.5 i
ECCS SUBSYSTEMS - T
> 290*F y*
LIMITING CONDITION FOR OPERATION 1.5.2 Two indepenecnt Etts subsystems shall be OPERAELE with each subsystem cer!.orised of:
One OPERA 5LE high pressure injection (HP:) pum;.
a.
b.
One OPERABLE low pressure injecticn (LPI) Fump, c.
One OPERABLE decay heat cooler, and d.
An 0FIRABLE flow path ca;tble of taking suction fr:rn the berated water stcrate tant (BVST) on a safety injection signal anc manus 11y transferring suction to the containment sump l
during the recirculation phase of operation.
AFFLlCi!1LITY,: MCDES 1, 2 and 3.
ACTION:
a.
Wita one ECC5 subsystem inoperable, restore the inoperable subsystem to OPEP'_. ! status witnin 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in NOT SML'7DOWN within the next 12 heters.
t b.
In the event the EttS is actuated and injects water into the Reacter teolant System, a Special Report sna11 be :repared and submitted to the Ccon.issien pursuant te Specificati~en 6.9.2 within 90 days describing the circumstances of the actuation and the total accumulated artilation Cycles tD data.
SURVEILLANCE R!001REw.Eh7 4.5.2 Each ECCS subsystem shall be demonstrated CPERABLE:
a.
At least once per 31 days by verifying that each valve (manual, pcwer operated or automatic) in the ficw path that is not 1ccked, sealed er otherwise secured in position, is in its ccrrect pcsition.
DAVI' ' 15E, UNIT 1 3/4 5.-3 knendment No. 36 P00R ORl81RAL
' EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS b.
At least once per 18 months, or prior to operation after ECCS piping has been drained by verifying that the ECCS piping is full of water by venting the ECCS pump casings and discharge piping high points.
I By a visual inspection which verifies that no loose debris c.
(rags, trash, clothing, etc.) is present in the containment which could be transported to the containment emergency sump and cause restriction of the pump suction during LOCA conditions.
This visual inspection shall be performed:
1.
For all accessible areas of the containment prior to establishing CONTAINMENT INTEGRITY and 2.
Of the areas affected within containment at the completion of each containment entry when CONTAINMENT INTEGRITY is established.
d.
At least once per 18 months by:
1.' Verifying that the interlocks:
a) Close DH-11 and DH-12 and deenergize the pressurizer heaters, if either DH-11 or DH-12 is open and a simulated reactor coolant system pressure which is greater than the trip setpoint (<438 psig) is applied, b) Prevent the opening of DH-11 and DH-12 when a simulated or actual reactor coolant system pressure which is greater than the trip setpoint (<438 psig) is applied.
2.
a) A visual inspection of the containment emergency sump l
which veriffes that the subsystem suction inlets are not restricted by debris and that the sump components (trash racks, screens, etc.) show no evidence of structural distress or corrosion.
b) Verifying that on a Borated Water Storage Tank (BWST)
Low-Low Level interlock trip, the BWST Outlet Valve HV-DH7A (HV-DH7B) automatically close in <75 seconds after the operator manually pushes the coiitrol switch to open the Containment Emergency Sump Valve HV-DH9A (H]-DH98) which should be verified to open in 175 seconds.
3.
Verifying a total leak rate 1 20 gallons per hour for the LPI system at:
a) Normal operating pressure or hydrostatic test pressure of > 150 psig for those parts of the system downstream l
of the pump suction isolation valve, and I
l b) > 45 psig for the piping from the containment emergency
_sump isolation valve to the pump suction isolation valve.
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DAVIS-BESSE, UNIT 1 3/4 5-4 Amendment No. 3. 75, pg,40
~
EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REOUIREMENT3 (Continued) 4.
Verifying that a minimum of 72 cubic feet of solid granular i
L; trisodium phosphate dodecahydrate (TSP) is contained within'the
. TSP storage baskets.
-i n'
5.
Verify that a representative sample of TSP from a TSP storage basket has a density of > 53 lbs/cu ft.
6.
Verifying that when a representative sample of 0.35 1 0.05 lbs of TSP from a TSP storage basket is submerged, without agitation, in 5015 gallons of 180 + 10*F borated water from the BWST, the pH of the mixed solution is raised to,
3,6 within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
At least once per 18 months, during shutdown', by e.
1.
Verifying that each automatic valve in the flow path actuates to its correct position on a safety injection test signal.
2.
Verifying that each HPI and LPI pump starts auto-matica11y upon receipt of a SFAS test signal.
f.
By performing a vacuum leakage rate test of the watertight enclosure for valves DH-11 and DH-12 that assures the motor operators on valves DH-ll and DH-12 will not be flooded for at least 7 days following a LOCA:
1 At least once per 18 months.
2.
After each opening of the watertight enclosure.
3.
After any maintenance on o. modification to the watertight enclosure which could affect its integrity.
g.
By verifying the correct position of each mechanical position stop for valves DH-14A and DH-14B.
1.
Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> following completion of the opening of the valves to their mechanical position stop or following completion of maintenance on the valve when the LPI system is required to be OPERABLE i-2.
At least onc'e per 18 months.
l jDAVIS-EESSE, UNIT 1 3/4 5-5 Amendment No. St. 40 l
.