ML20078S872
| ML20078S872 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 02/16/1995 |
| From: | Oconnor P Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20078S873 | List: |
| References | |
| GL-91-08, GL-91-8, NUDOCS 9502270359 | |
| Download: ML20078S872 (7) | |
Text
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UNITED STATES
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3 NUCLEAR REGULATORY COMMISSION i
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WASHINGTON, D.C. MSN T
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ENTERGY OPERATIONS. INC.
SYSTEM ENERGY RESOURCES. INC.
SOUTH MISSISSIPPI ELECTRIC POWER ASSOCIATION i
MISSISSIPPI POWER AND LIGHT COMPANY-DOCKET NO. 50-416 GRAND GULF NUCLEAR STATION. UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE i
Amendment No. 116 f
License No. NPF-29 l.
The Nuclear Regulatory Commission (the Commission) has found that:
A.
The application for amendment by Entergy Operations, Inc. (the licensee) dated July 14, 1993 complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act),
and the Commission's rules and regulations set forth in 10 CFR i
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 Commission'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 i
E.
The issuance of thi amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
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to the Technical
_Accordingly, the license is amended by changes Specifications, as indicated in the attachment to this license amen 2.'
and paragraph 2.C.(2) of facility Operating License No. NPF-29 is amended to read as follows:
(2) Technical Soecifications The Technical Specifications contained in Appe through Amendment No.116, are hereby incorporated into this i
Entergy Operations, Inc. shall operate the facility in accordance with the Technical Specifications and the Environment license.
Protection Plan.
This license amendment is effective as of its date of issuance.
3.
FOR THE NUCLEAR REGULATORY COMMISSION Paul W. O'Connor, Senior Project Manager Project Directorate IV-I Division of Reactor Projects - III/IV Office of Nuclear Reactor Regulation
Attachment:
Changes to the Technical Specifications Date of Issuance: February 16, 1995 i
s
ATTACHMENT TO LICENSE AMENDMENT NO.116 FACILITY OPERATING LICENSE N0. NPF-29 DOCKET NO. 50-416 fleplace 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 PAGES INSERT PAGES 3/4 6-59 3/4 6-59' 3/4 6-60 thru 3/4 6-60 3/4 6-66 B 3/4 6-8b B 3/4 6-9 B 3/4 6-9
CONTAINMENT SYSTEMS
[0NTAINMENT AND DRYWELL HYDROGEN IGNITION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.7.2 The containment and drywell hydrogen ignition system consisting of two independent containment and drywell hydrogen ignition subsystems shall be OPERABLE with each subsystem consisting of at least 90% of its igniter assemblies operable.
APPLICABILITY: OPERATIONAL CONDITIONS I and 2 ACTION:
With one containment and drywell hydrogen ignition subsystem inoperable, I
restore the inoperable subsystem to OPERABLE status within 30 days or be in at i
least 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 RE0VIREMENTS 4.6.7.2 The ccntainment and drywell hydrogen ignition system shall be demonstrated OPERABLE:
a.
At least once per 184 days by energizing the supply breakers for each igniter circuit and performing current / voltage measurements of each circuit.
If more than 3 of the included igniter assemblies of either subsystem are determinud to be inoperable, increase the surveillance frequency to a 92-day interval until the condition no longer exists.
b.
At least once per 18 nonths, by energizing each glow plug and:
1.
verifying a surface temperature of at least 1700*F for each of the accessible igniters, and 2.
verifying by measurements sufficient current / voltage to develop 1700'F surface temperature for those igniter assemblies in inaccessible areas.
t-GRAND GULF-UNIT 1 3/4 6-59 Amendment No. 116
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i CONTAINMENT SYSTEMS-i l
'COMBUSTIRLE GAS CONTROL PURGE SYSTEM i
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. LIMITING CDR DN FOR OPERATION 3.6.7.3 Two independent drywell purge system subsystems shall be OPERABLE.
t APPLICABILITY: OPERATIONAL CONDITIONS I and 2.
ACTION:
1 With one drywell purge system subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 30 days or be in at least 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 />, j
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SVRVEILLANCE RE0VIREMENTS 4.6.7.3 Each drywell purge system subsystem shall be demonstrated OPERABLE:
a.
At least once per 92 days by:
1.
Starting the subsystem from the control room, and i
2.
Verifying that the system operates for at least 15 minutes.
At l' ast once per 18 months by:
b.
e 1.
Verifying a subsystem flow rate of at least 1000 cfm during subsystem operation for at least 15 minutes.
i 2.
Verifying the pressure differential required to open the vacuum breakers on the drywell purge compressor discharge j
lines, from the closed position, to be less than or equal to l
1.0 psid.
t I
Verifying the OPERABILITY of the drywell purge compressor discharge i
c.
line vacuum breaker isolation valve differential pressure actuation instrumentation with an opening setpoint of 0.0 to 1.0 psid (Drywell minus Containment) by performance of a:
l.
CHANNEL CHECK at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, 2.
CHANNEL FUNCTIONAL TEST at least once per 31 days, and 3.
CHANNEL CALIBRATION at least once per !8 months.
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GRAND GULF-UNIT 1 3/4 6-60 Amendment No.116
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l 00NTAINMENT SYSTEMS BASES SECONDARY CONTAINMENT (Continued)
The surveillance testing for verifying heat dissipation for the Standby.
Gas Treatment System heaters is performed in accordance with ANSI N510-1975 with the exception of the 5% current phase balance criteria of Section 14.2.3.
The 6
offsite power system for the Grand Gulf Nuclear Station consists of a non-transpositional 500-kV grid. The grid has an inherent unbalanced load distri-i bution which results in unbalanced voltages in the plant. Voltage unbalances exceeding the ANSI N510-1975 5% criteria are not atypical.
For painting, fire and chemical releases other than carbon dioxide in any ventilation zone com-municating with the standby gas treatment system, the surveillance requirements are adequate to ensure charcoal adsorbency is maintained. A release of carbon dioxide for any reason other than a fire will not adversely affect the char-coal's adsorbency and the surveillance requirement need not be performed.
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GRAiCD GULF-UNIT 1 B 3/4 6-8b Amendment No. 116 i
CONTAINMENT SYSTEMS BASES 3/4.6.7 ATMOSPHERE CONTROL The OPERABILITY of the systems required for the detection and control of hydrogen gas ensures that these systems will be available to maintain the hydrogen concentration within the containment below its flammable limit during post-LOCA conditions. The drywell purge system in combination with the hydrogen recombiner system is designed to control the hydrogen produced following a DBA LOCA.
The hydrogen ignition system is used to control the excessive quantity of hydrogen during the unlikely occurrence of a degraded core accident.
Both the hydrogen recombiner and the hydrogen ignition systems are capable of controlling the expected hydrogen generation associated with (1) zirconium-water reactions, (2) radiolyt c decomposition of water, and (3) corrosion of metals within containment.
Two 100% capacity hydrogen recombiners are provided for the control of hydrogen in the containment.
Either recombiner is capable of maintaining the hydrogen concentration below the flammability limits following a DBA LOCA.
Two 100% drywell purge systems are the primary means of H2 control within the drywell.
Either system is canable of purging hydrogen produced following a LOCA into the containment volume. Hydrogen generated from the metal-water reaction and radiolysis is assumed to evolve to the drywell atmosphere and form a homogenous mixture through natural forces and mechanical turbulence (ECCS pipe break flow).
The drywell purge system forces drywell atmosphere through the horizontal vents and into the containment and as a result no bypass path exists.
The hydrogen control system is consistent with the recommendations of GDC 41,
Containment Atmosphere Cleanup" and the recommendations of Regulatory Guide 1.7, " Control of Combustible Gas Concentrations in Containment following a LOCA," September 1976.
The primary containment and drywell hydrogen ignition system is a part of l
the combustible gas control system required by 10 CFR 50.44 to reduce the hydrogen concentration in the primary containment following a degraded core accident.
Ignitors are distributed throughout the primary containment and i
drywell. The OPERABILITY of at least 90% of ianiter assemblies in either hydrogen ignition subsystem will maintain an effective coverage throughout the containment and drywell.
Some areas may be categorized as inaccessible areas due to high levels of radiation or personnel safety.
Examples of inaccessible areas include such enclosures as the heat exchanger, filter demineralizer, and the reactor water clean-up pump rooms.
Special surveillance requirements are provided for igniters located in inaccessible areas to reduce personnel exposure and other safety concerns. A list of required hydrogen igniters is contained in applicable plant procedures by electrical division / circuit and physical i
location.
GRAND GULF-UNIT 1 B 3/4 6-9 Amendment No.116