ML20212C835
| ML20212C835 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 12/22/1986 |
| From: | Stolz J Office of Nuclear Reactor Regulation |
| To: | Toledo Edison Co, Cleveland Electric Illuminating Co |
| Shared Package | |
| ML20212C842 | List: |
| References | |
| NPF-03-A-096, TAC 55782 NUDOCS 8612310216 | |
| Download: ML20212C835 (10) | |
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o UNITED STATES E"
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l TOLED0 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. 96 License No. NPF-3 1.
The Nuclear Regulatory Comission (the Comission) has found that:
A.
The application for amendment by the Toledo Edison Company and The Cleveland Electric Illuminating Company (the licensees) dated August 27, 1984, as supplemented August 29, 1985, 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 (i) 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 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 Comission'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.C.(2) of Facility Operating License No. NPF-3 is hereby amended to read as follows:
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. Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 96, 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 within 14 days.
FOR THE NUCLEAR REGU ATORY COMMISSION 2i do m F. Stolz, Director P 1 Pro.iect Directora
- 6 vision of PWR Licensing-B
Attachment:
Changes to the Technical Specifications Date of Issuance: December 22, 1986 8
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ATTACHMENT TO LICENSE AMENDMENT N0. 96 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. The corresponding overleaf pages are also provided to maintain document completeness.
Remove Insert 3/4 7-4 3/4 7-4 3/4 7-5 3/4 7-5 3/4 7-Sa B 3/4 7-2 B 3/4 7-2 l
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TABLE 4.7-_1 STEAM LINE SAFETY VALVES PER STEAM GENERATOR 5
m NUMBER PER STEAM GENERATOR LIFT SETTING (t 1%)*
E Z
a.
2 1050 psig b.
2 1070 psig c.
3 1090 psig d.
2 1100 psig 3
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- The lift setting pressure shall correspond to ambient conditions of the valve at nominal operating temperature and pressure.
PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 Two independent steam generator auxiliary feedwater pumps and associated flow paths shall be OPERABLE.
APPLICABILITY: MODES 1, 2 and 3*.
l ACTION:
With one Auxiliary Feedwater System inoperable, restore the a.
inoperable system to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.7.1.2 Each Auxiliary Feedwater System shall be demonstrated OPERABLE:
At least once per 31 days on a STAGGERED TEST BASIS by:
a.
- 1..
Verifying that each steam turbine driven pump develops a differential pressure of > 1070 psid on recirculation flow when the secondary steam supply pressure is greater than 800 psia, as measured on PI SP 12B for pump 1-1 and PI SP 12A for pump 1-2.
2.
Verifying that each valve (power operated or automatic) in the flow path is in its correct position.
3.
Verifying that all manual valves in the auxiliary feedwater pump suction and discharge lines that affect the system's capacity to deliver water to the steam generator are locked in their proper position.
b.
At least once per 18 months by:
1.
Verifying that each automatic valve in the flow path actuates to its correct position on an auxiliary feed-water actuation test signal prior to entering MODE 3.
- 2.
Verifying that each pump starts automatically upon receipt of an auxiliary feedwater actuation test signal prior to entering MODE 2.
3.
Verifying that there is a flow path between each auxiliary feedwater pump and each steam generator by pumping water from the Condensate Storage Tank to the steam generator.
- Provision of section 3.0.4 is not applicable for entry into MODE 3.
DAVIS-BESSE, UNIT 1 3/4 7-4 Amendment No. 96
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
The flow path to the steam generator shall be verified prior to entering MODE 3 by either steam generator level change or. Auxiliary Feedwater Safety Grade Flow Indication. Verification of the Auxiliary Feedwater System's flow capacity is not required.
The Auxiliary Feed Pump Turbine Steam Generator Level Control 1
c.
System shall be demonstrated OPERABLE by performance of a CHANNEL CHECK at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, a CHANNEL FUNCTIONAL TEST at least once per 31 days, and a CHANNEL CALIBRATION at least once per 18 months.
d.
The Auxiliary Feed Pump Suction Pressure Interlocks, and Auxiliary Feed Pump Turbine Inlet Steam Pressure Interlocks shall be demonstrated OPERABLE by performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days, and a CHANNEL CALIBRATION at least once per 18 months.
After any. modification or repair to the Auxiliary Feedwater e.
System that could affect the system's capability to deliver water to the steam generator, the affected flow path shall be demonstrated available as follows:
1.
If the modification or repair is downstream of the test flow line, the auxiliary feed pump shall pump water from the Condensate Storage Tank to the steam generator; and the flow path availability will be verified by steam generator level change or Auxiliary Feedwater Safety Grade Flow Indication.
2.
If the modification or repair is upstream of the test flow line, the auxiliary feed pump shall pump water through the Auxiliary Feedwater System to the test flow line; and the flow path availability will be verified by f1cw indication in the test flow line.
(see note below)
This Surveillance Testing shall be performed prior to entering MODE 3 if the modification is made in MODES 4, 5 or 6.
Verification of the Auxiliary Feedwater System's flow capacity is not required.
Note:
When conducting tests of the Auxiliary Feedwater System in MODES 1, 2, and 3 which require local manual realignment of valves that make the system inoperable, a dedicated individual shall be stationed at the valves (in communication with the control room) able to restore the valves to normal system OPERABLE status.
1 DAVIS-BESSE, UNIT 1 3/4 7-5 Amendment No. 43, 63, 96
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) i f.
Follcwing each extended cold shutdown (> 30 days in MODE 5), by:
1.
Verifying that there is a flow path between each auxiliary feedwater pump and each steam generator by pumping Condensate Storage Tank water to the steam generator. The flow path to the steam generator shall be verified by either steam generator level change or Auxiliary Feedwater Safety Grade Flow Indication.
Verification of the Auxiliary Feedwater System's flow capacity is not required.
i DAVIS-BESSE, UNIT 1 3/4 7-Sa Amendment No. 96
m PLANT SYSTEMS i
l CONDENSATE STORAGE TANK l
LIMITING CONDITION FOR OPERATION 3.7.1.3 The condensate storage facilities (condensate storage tank and deaerator storage tank) shall be OPERABLE with a minimum contained volume of 250,000 gallons of wat'er.
APPLICABILITY: MODE 5 1, 2 and 3.
ACTION:
With the condensate storage facilities inoperable, within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.either:
a.
Restore the condensate storage facilities to OPERABLE status or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, or b.
Demonstrate the OPERABILITY of the service water system as a backup supply to the auxiliary feedwater system and restore the condensate storage facilities to OPERABLE status within 7 days or be in HOT. SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
SURVEILLANCE REOUIREMENTS.
4.7.1.3.1 The conder: sate storage facilities shall be demonstrated OPERABLE 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 verifying the contained water volume to be within its limits when the facilities are the supply source for the auxiliary feedwater pumps.
4.7.. l. 3. 2 The service water system shall be demonstrated OPERABLE 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 verifying that at least one service water loop is operating and that the service water loop-auxiliary feedwater system isolation valves are either open or OPERABLE whenever the service water system is the supply source for the auxiliary'feedwater pumps.
DAVIS-BESSE, UNIT 1 3/4 7-6
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' 3/4.7 PLANT SYSTEMS EASES 3/4.7.1 TURBINE CYCLE 3/4.7.1.1 SAFETY VALVES The OPERABILITY of the main steam Ifne code safety valves ensures that the secondary system pressure will be limited to within 1105 fts design pressure of 1050 psig during the most severe anticipated system operational transient. The maximum relieving capacity is associated with a turbine trip from 1001 RATED THERMAL POWER coincident with an assumed loss of condenser heat sink (i.e.. no steam bypass tc the condenser).
. The 'specified valys lift settings and relieving capacities are in accordance with the requirements of Section III of the ASME Boiler and Pressure Vassel Code.1971 Edition. The total relieving capacity for all valves on all of the s. team lines is 14.175,000 lbs/hr whir.h is 120 percent of the total secondary steam flow of 11.760.000 lbs/hr at 1005 RATED THERMAL POWER. A minimum of 2 OPERABLE safety valves per steam generator ensures that sufficient relieving capacity is available for the allowable THERMAL. POWER restriction in Table 3.7-1.
STARTUP and/or POWER OPERATION is allowable with safetrvalves inoperable within the limitations of the ACTION requirmnents on the basis of the reduction in secondary systen steam flow and THERMAL POWER required by the reduced reactor trip settings of the High Flux channels. The reactor trip setpoint reductions are derived on the following bases:
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.i SP =
x W
Z where:
SP = reduced Trip Setpoint in*krcent of RATED THERMAL POWER (Not.to Exceed W)
V a. maximum number of inoper~able safety valves per steam generator-
.W = High Flux Trip Setpoint for four pump operation as specified in Table 2.2-1 X = Total relieving capacity of all safety valves per. steam generator in 1bs/ hour. 7.087.500 lbs/ hour Y = Maximum relieving capacity of any one safety valve in 1bs/ hour, 845.759 lbs/ hour Z = Required relieving capacity per steam generator in 1bs/hr, 6 S85,600 lbs/hr.
DAVIS-BESSE, UNIT 1 B 3/4 7-1 Amendment No.-48
PLANT SYSTEMS BASES.
3/4.7.1.2 AUXILIARY FEEDWATER SYSTEMS The OPERABILITY of the Auxiliary Feedwater Systems ensures that.the j
Reactor Coolant System can be cooled down to less than 280*F from normal operatin'g conditions in the event of a total loss of offsite power.
Each steam driven auxiliary feedwater pump is capable of delivering a total feedwater flow of 800 gpa at a pressure of 1050 psig to the entrance of the steam generators. This capacity is sufficient to ensure that adequate feedwater flow is available to remove decay heat and reduce the Reactor Coolant System temperature to less than 280*F where the Decay Heat Removal System may be placed into operation.
Following any modifications or repairs to the Auxiliary Feedwater i
System piping _from the Condensate Storage Tank through auxiliary feed pumps to the steam generators that could affect the system's capability to deliver water to the steam generators, following extended cold i
shutdown, a flow path verification test shall be performed. This test i
may be conducted in NODES 4, 5 or 6 using auxiliary steam to drive the i
auxiliary feed pumps turbine to demonstrate that the flow path exists from the Condensate Storage Tank to the steam generators via auxiliary
]
feed pumps.
3/4.7.1.3 CONDENSATE STORAGE FACILITIES The OPERABILITY of the Condensate Storage Tank,with the minimum l
i water volume ensures that sufficient water is available to maintain the RCS at HOT STANDBY conditions for 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> with steam discharge to atmosphere and to cooldown the Reactor Coolant System to less than 280'F in the event of a total loca of offsite power or of the main feedwater system. The contained water volume limit includes an allowance for water not usable because of tank discharge line location or other physical characteristics.
3/4.7.1.4 ACTIVITY The limitations on secondary system specific activity ensure that the resultant offsite radiation dose will be limited to a small fraction of 10 CFR Part 100 limits in the event of a steam line rupture. This dose includes the effects of a coincident 1.0 GPM primary to secondary tube leak in the steam generator of the affected steam line. These values are consistent with the assumptions used in the safety analyses.
3/4.7.1.5 MAIN STEAM LINE ISOLATION VALVES The OPERABILITY of the main steam line isolation valves ensures that no more than one steam generator will blowdown in the event of a steam line rupture. This restriction is required to 1) minimize the k
s DAVIS-BESSE, UNIT I B 3/4 7-2 Amendment No. SS, 96
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