ML20087K161
| ML20087K161 | |
| Person / Time | |
|---|---|
| Site: | Hatch  |
| Issue date: | 03/06/1984 |
| From: | Stolz J Office of Nuclear Reactor Regulation |
| To: | Georgia Power Co, Oglethorpe Power Corp, Municipal Electric Authority of Georgia, City of Dalton, GA |
| Shared Package | |
| ML20087K162 | List: |
| References | |
| TAC 51998, DPR-57-A-099 NUDOCS 8403260048 | |
| Download: ML20087K161 (9) | |
Text
_ #pn Knaug%g UNITED STATES l -
I NUCLEAR REGULATORY COMMISSION o
h '-
- WASHINGTON, D. C. 20555 i
GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DALTON, GEORGIA DOCKET NO. 50-321 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 99 License No. DPR-57 1.
The Nuclear Regulatory Comission (the Comission) has found that:
A.
The application for amendment by Georgia Power _ Company, et al.,
(the licensee) dated April 22, 1983, 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 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 license 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 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 attachmenc to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-57 is hereby amended to read as follows:
8403260048 840306 PDR ADOCK 05000321 P
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Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 99, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.
3.
This license amendment is effective as of its date of issuance.
FOR THE'NUCLEA REGyLATORYCOMMISSION Joh F. Stolz, Chief '
Operating Reactors Br ch #4 Division of Licensing
Attachment:
Changes to the Technical Specifications Date of Issuance: March 6, 1984
6 ATTACHMENT TO LICENSE AMENDMENT N0.99 FACILITY OPERATING LICENSE NO. DPR-57 DOCKET NO. 50-321 4
l Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain a vertical line indicating the area of change.
Remove Insert 3.2-22 3.2-22 3.2-48 3.2-48 3.7-10 3.7-10 3.7-10a 3.7-10a 3.7-33a 3.7-33a 3.7-34 3.7-34 4
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'g Table 3.2-11 IllSTRUf1EllTATIO!! UlllCll PROVIDES SUI!VEILLAtlCE lilf0Rf1AT10fl E.
- 4 Required A
Ref.
. Ilo.
Instrument Instrument Type and A,
_[ak (b)
_ Channels I
Range _
Action Rema rl:s
' E 1
Reactor llater Level (GE/IIAC) 1 Recorder (c)
(d) 2 Indicator 0 to 60" (c)
(d) w 2
Shroud Water Level 1
Recorder (c)
(d)
M 1
Indicator -31/" to -17" (c)
(d) m 3-Reactor Pressure 1
Recorder (c)
(d) 2 Indicator 0 to 1200 psig (c)
(d)'
4 Drywell Presscre 2
Recorder -5 to +80 psig (c)
.(d) w 5
Drywl1 Temperature 2
Recorder 0 to 500 F (c)
(d)
,ro g
6 Suppression Chamb'er Air Temperature 2
Recorder 0 to 500"F (c)
(d) 7 Suppression Chamber Water Temperature 2
Recorder 0 to 250"F (c)
(d) t 8
Suppression Chamber Water Level 2
Indicator 0 to 300" (c)
(d) 2 Recorder 0 to 30" (c)(c)
(d) 9 Suppression Chamber Pressure 2
Recorder -5 to +80 psig (c)
(d) 10 Rod Position Information System (RPIS) 1 28 Volt Indicating Lights (c)
(d) 11 Ilydrogen and Oxygen Analyzer 1
Recorder 0 to 52 (c)
(d) 12 Post LOCA Radiation 11onitoring System 1
Recorder (c)
(d) 6 Indicator 1 to 10 R/hr (c)
(d) 13 a) Safety / Relief Valve Position Primary 1
Pressure Switch 4-100 psig
( f)
Indicator b) Safety /llelief Valve Position Secondary 1 Temperature element 0-600"F
( f)
Indicator
g Table 4.2-11 no E
Check and Calibration flinimum Frequency for Instrunentation
,8, ilhich Provides Surveillance Infonaation g
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z Ref.
Ins trunent Instrinnent Check Instrument Calibration flo.
Ilinimum Fiequency flinimuni Frequency (a)
(b) i (c)
E
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1 Reactor llater Level Each shift Every G r?x)iiths y*
(GE/11AC)
E 2
Siiroud 11ater Level Each shift Every 6 months 3
Reactor Pressure Each shift Every 6 months 4
Drywell. Pressure Each sliift Every 6 nonths 5
. Drywell Temperature Each shift Every G oionths l
F 6
Suppression Chamber Air Each shift Every 6 inontiis
'?
Tempera ture 7
Suppression Chamber llater Each shift Every 6 months Tempera ture 8
Suppression Chaniber llater Each shift Every 6 months Level 9
Suppression Chamber Each slii f t Every 6 months Pressure 10 Rod Position Infonnation Each shift fl/A System (RPIS) 11 llydrogen and Oxygen Each shift Every 6 anonths Analyzer 12 Post LOCA Radiation Each sliif t Every 6 iaonths 13 a) Safety / Relief Valve Position Pri-flonthly Every 18 months mary Indicator b) Safety / Relief Valve Position flonthly Every til months Secondary Indicator.
LI:'IT:NG CONDIT:0NS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.7.A.C.c.
H, and 0, Analv:er 4.7.A.6.c.
H and 0 Analyzer 2
2 Whenever the reactor is in power Instrumentation surveillance is operation, there shall be at least listed in Table 4.2-11.
one CAD System H2 and 02 analyzer serving the primary containment.
If one H2 and 02 analyzer is in.
ooerable, the reactor may remain in coeration for a period not to exceed seven days.
d.
Post-LOCA Reoressurization Limit Tne maximum post-LOCA primary con-tainment repressurization limit alicuable using the CAD System shall be 30 psig. Venting via the SGTS to the main stack must be I
initiated at 30 psig following the initial post-LOCA pressure peak.
d 3.7-10 Amendment No. EE, S$, SE, 99
1 LIMITli1G COMDii10.*iS FCR OPERATION SURVEILLANCE REQUIREMENTS i
7.
Shutdown Renuirements If Specification 3.7.A cannot be-met, an orderly shutdown shall be initiated and the reactor shall be brought to Hot Shutcown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and shall be in the Cold Shut-down condition within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
B.
Standbv Gas Treatment System-B.
Standby Gas Treatrent System 1.
Ocerability Renuirenents 1.
Surveillance When System operaole A ninimum of three (2 of 2 in Unit 1 and 1 of 2 in Unit 2) of the four in-At least once per coerating dependent standby gas treatmer.t system cycle, not to exceed 18 months, trains snall be operable at all times the following conditions shall when Unit 1 secondary containment be demonstrated:
integrity is required, a.
Pressure drop across the With one of the Unit I standby gas combined HEPA filters and treatment systems inoperable, for charcoal absorber banks is any reason, Unit I reactor coeration less than 6 incaes of water and fuel handling and/or handling of at the system design flow casks in the vicinity of the scent rate (+105, -05).
fuel pools is permissible for a period of seven (7) days provided b.
Operability of inlet heater that all active conconents in the at rated power when, tested remaining standoy gas treatment in accordance with ANSI systems in each unit shall be N510-1975.
demonstrated to be operable within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, and daily thereafter.
c.
Air distribution is uniform within 20% across the filter train when tested in accordance with ANSI N510-1975.
4 4
3.7-10a Amtndment No. 55. 55, 99
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EASES FOR L1:11ili!G C0:!DIT10tlS FOR OPERA 110:1 This page is left intentionally blank
)
3.7-33a AmIndment No. 55, 99
l 3ASES FOP. LIIIITI iG CONDITIO!!S IOR OPERATIO:1
+
3.7.A.7.
Shutdown Recuirerrents Bases for shutdown recuirements are discussed above in conjunction with the in-dividual requirements for primary containment integrity.
B.
Standby Gas Treatment Svstem The standby gas treatment systems are designed to filter and exhaust the Unit 1 secondary containment atmoschere to the off-gas stack during secondary contain-ment isolation conditions, with a mininum release of radioactive materials from these areas, to the environs. The Unit 1 standby gas treatment system fans are designed to automatically start uoon receipt of a high radiation signal from either the Unit 1 or Unit 2 refueling floor ventilation exhaust duct nonitors or the Unit i reactor building ventilation exhaust duct monitors, or upon receipt of a signal from the Unit 1 primary containment isolation system. The Unit 2 standby gas treatment system fans are designed to automatically start, to assist the Unit I fans to exhaust the Unit 1 secondary containment atnosphere I
upon receipt of a high radiation signal from either the. Unit 1 or Unit 2 re-fueling floor ventilation exhaust duct monitors or the Unit I reactor buildina ventilation exhaust duct nonitors, or upon receipt of c signal from the Unit 1 primary containment isolation system.
In addition, the systems may also be started manually, from the Main Control Room.
l In the_ case of the Unit I standby gas treatment system, upon receiot of any of I
the isolation signals, both fans start, isolation dangers open and each fan draus air from the isolated Unit 1 secondary containment.
In the case of 'the Unit 2 standby gas treatment system, upon receipt of an l
isolation signal from the Unit 1 prinary containnent isolation system, reactor building ventilation exhaust duct monitors, or the Unit 1 or Unit 2 refueling floor ventilation exhaust duct monitors, both fans start, fan supply and discharge dampers open, and the fans draw air frca the isolated Unit 1 secondary containment.
Once the SGTS systems have been initiated autonatically, the operator may place any one of the Unit 1 and Unit 2 trains in the standby mode provided the re-maining train in each unit is operable. Should a failure occur in the remain-ing operating trains, resulting in air flow reduction below a preset value, the standby systems will restart automatically.
As a minimum for operation, one of the two Unit I standby gas treatment trains and one of the two Unit 2 standby ga's treatment trains is reouired to achieve the design differential pressure, given the design building infiltration rate.
Once this design differential pressure is achieved, any leakage past the secondary containment boundary shall be inleakage.
A detailed discussio.. of the standby gas treatment systems may be found in Section 5.3.3.3 of the Unit 1 FSAR, and in Section 6.2.3 of the Unit 2 FSAR.
Any one of the four filter trains has sufficient absorption capacity to pro-vide for cleanup of the Unit I secondary containment atmosphere following containment isolation. Any one of the four available standby gas treatment trains may be considered an installed spare. Therefore, with one of the standby gas treatment trains in each unit inocerable, there is no imediate threat to the Unit 1 containment system performance, and reacter operation or fuel handling operations may continue while repairs are being made.
Should either or both of the remaining standby gas treatment trains be found to be inoperable, the Unit 1 plant should be placed in a condition that does 'not require a standby gas treatment system.
Amendment No. M,99 3.7-34
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