ML20214X044
| ML20214X044 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 12/03/1986 |
| From: | Butler W Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20214X047 | List: |
| References | |
| TAC-61881, NUDOCS 8612100517 | |
| Download: ML20214X044 (10) | |
Text
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NUCLEAR REGULATORY COMMISSION r,
4j ivASHINGTON, D. C. 20555
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MISSISSIPPI POWER & LIGHT COMPANY MIDDLE SOUTH ENERGY, INC.
SOUTH MISSISSIPPI ELECTRIC POWER ASSOCIATION DOCKET NO. 50-416 GRAND GULF NUCLEAR STATION, UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 25 License No. NPF-29
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1.
The Nuclear Regulatory Comission (the Comission) has found that A.
The application for amendment by Mississippi Power & Light Company, Middle South Energy, Inc., and South Mississippi Electric Power Association, (the licensees) dated June 26, 1986, 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 i
E.
The issuance of this amendment is in accordance with 10 CFR Pcrt 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-29 is hereby amended to read as follows:
Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 25, are hereby incorporated into this license..
Mississippi Power & Light Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
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. 3.
This license amendment is effective as of its date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION Ogleken edgwd by Walter R. catler, Director BWR Project Directorate No. 4 Division of BWR Licensing
Attachment:
Changes to the Technical Specifications Date of Issuance:
December 3,1986 l
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This license amendment is effective as of its date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION
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Walter R. Butler, Director BWR Project Directorate No. 4 Division of BWR Licensing
Attachment:
Changes to the Technical Specifications Date of Issuance:
December 3,1986 1
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- g AT,TACHMENT TO LICENSE AMENDMENT NO. 25 FACILITY OPERATING LICENSE NO. NPF-29 DOCKET NO. 50-416 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. Overleaf pages provided to maintain document completeness.*
Remove Insert 3/4 3-79 3/4 3-79 3/4 3-80 3/4 3-80*
3/4 7-5 3/4 7-5*
3/4 7-6 3/4 7-6 B 3/4 3-5 8 3/4 3-5 B 3/4 3-6 B 3/4 3-6*
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INSTRUMENTATION CHLORINE DETECTION SYSTEM LIMITING CONDITION FOR OPERATION 3.3.7.8 DELETED SURVEILLANCE REQUIREMENTS 4.3.7.8 DELETED 1
GRAND GULF-UNIT 1 3/4 3-79 Amendment No. 25 l
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INSTRLMENTATION FIRE DETECTION INSTRUNENTATION
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LINITING CONDITION FOR OPERATION 3.3.7.9 As a minimum, the fire detection instrumentation for each fire detection zone shown in Table 3.3.7.9-1 shall be OPERABLE.
APPLICABILITY: Whenever equipment protected by the fire detection instrument is required to be OPERABLE.
ACTION:
With the number of OPERABLE Function A or Function B fire detection instruments icss than the Minimum Instruments OPERABLF, requirement of Table 3.3.7.9-1:
Within I hour, establish a fire watch patrol to inspect the zone (s) a.
with the Function A or room (s) with Function B inoperable instru-ment (s) at least once per hour, unless the instrument (s) is located inside the containment, steam tunnel or drywell, then inspect the primary containment at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or monitor the contain-ment, steam tunnel and/or drywell air temperature at least once per
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hour at the locations listed in Specification 3.7.8, 4.6.1.8 and M
4.6.2.6.
b.
Restore the minimum number of instruments to OPERABLE status within 14 days or prepare and submit a Special Report to the Commission pur-suant to Specification 6.9.2 within 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the instrument (s) to OPERABLE status.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
- c.
i SURVEILLANCE RE0t' RENENTS 4.3.7.9.1 Each of the above required fire detection instruments which are accessible during unit operation shall be demonstrated OPERABLE at least once per 6 months by perfomance of a CHANNEL FUNCTIONAL TEST. Fire detectors which are not acce,4sible during unit operation shall be demonstrated OPERABLE by the performanc<> of a CHANNEL FUNCTIONAL TEST during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless perfomed in the previous 6 months.
4.3.7.9.2 The NFPA Standard 72D supervised circuits supervision associated with the detector alarms of each of the above required fire detection instruments shall be demonstrated OPERABLE at least once per 6 months.
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I GRAND GULF-UNIT 1 3/4 3-80
PLANT SYSTEMS
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3/4.7.2 CONTROL ROOM EMERGENCY FILTRATION SYSTEM e.
LIMITING CONDITION FOR OPERATION 3.7.2 Two independent control room emergency filtration system subsystems shall be OPERABLE.
APPLICABILITY: All OPERATIONAL CONDITIONS and *.
ACTION:
In OPERATIONAL CONDITION 1, 2 or 3 with one control room emergency a.
filtration subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days or be in at least H3T SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
b.
In OPERATIONAL CONDITION 4, 5 or, *:
1.
With one control room emergency filtration subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days or initiate and maintain operation of the OPERABLE subsystem in the isolation mode of operation.
2.
With both control room emergency filtration subsystems' inoperable.
suspend CORE ALTERATIONS, handling of irradiated fuel in the J
primary or secondary containment and operations with a potential f
for draining the reactor vessel.
The provisions of Specification 3.0.3 are not applicable'in c.
g Operational Condition *.
s.
SURVEILLANCE REQUIREMENTS 4.7.2 Each control room emergency filtration subsystem shall be demonstrated j
l At least once per 31 days on a STAGGERED TEST BASIS by initiating, l
a.
from the control room,' flow through the HEPA filters and charcoal adsorbers and verifying that the subsystem operates for at least 10 continuous hours with the heaters OPERABLE.
b.
At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following j
painting, fire or chemical release in any ventilation zone communicating with the subsystem by:
1.
[DCLETED]
"When irradiated fuel is being. handled in the primary or secondary containment.
GRAND GULF-UNIT 1 3/4 7-5
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l PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 2.
Verifying that the subsystem satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.S.a. C.5.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is 4000 cfm 2 10%.
3.
Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Dosition C.6.b of Regulatory Guide 1.52, Revision 2 March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
4.
Verifying a subsystem flow rate of 4000 cfm t 10% during subsystem operation when tested in accordance with ANSI N510-1975.
e c.
After every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory l
Positon C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, neets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52 Revision 2, March 1978.
d.
At least once '
3 months by:
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Verifying wat the pressure drop across the combined HEPA filters M
and charcoal adsorber banks is less than 7.2 inches Water Gauge F
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while operating the subsystem at a flow rate of 4000 cfm i 10%.
7" 2.
Verifying that the subsystem receives an appropriate isolation I
actuation signal by each of the following test conditions. For at least one of the test conditions, verify that the subsystem automatically switches to the isolation mode of operation and the isolation valves close within 4 seconds.
(a) High high radiation in the outside air intake duct, (b) High drywell pressure, (c) Low low reactor water level, and (d) Manual initiation from the Control Room.
3.
Verifying that the heaters dissipate 20.7 i 2.1 kW when tested in accordance with ANSI N510-1975 (except for the phase belance criteria stated in Section 14.2.3).
e.
After each cosplete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to 99.95% of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 4000 cfm i 10%.
f.
After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 4000 cfm i 10%.
GRAND GULF-UNIT 1 3/4 7-6 Amendment No. 25 l
INSTRUMENTATION BASES 3/4.3.7.6 SOURCE RANGE MONITORS The source range monitors provide the operator with information of the status of the neutron level in the core at very low power levels during startup and shutdown. At these power levels, reactivity additions should not be made without this flux level information available to the operator. When the inter-mediate range monitors are on scale adequate inforration is available without the SRMs and they can be retracted.
The SRMs are required OPERABLE in OPERATIONAL CONDITION 2 to provide for rod block capability, and are required OPERABLE in OPERATIONAL CONDITIONS 3 and 4 to provide monitoring capability which provides diversity of protection to the mode switch interlocks.
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3/4.3.7.7 TRAVERSING IN-CORE PROBE SYSTEM l
The OPERABILITY of the traversing in-core probe system with the specified minimum complement of equipment ensures that the measurements obtained from use of this equipment accurately represent the spatial neutron flux distribution of the reactor core.
The TIP system OPERABILITY is demonstrated by normalizing all probes i
(i.e., detectors) prior to performing an LPRM calibration function. Monitoring core ther;nal limits may involve utilizing individual detectors to monitor Z
selected areas of the reactor core, thus all detectors may not be required to d
be OPERABLE. The OPERABILITY of individual detectors to be used for monitoring ll 1s demonstrated by comparing the detector (s) output with data obtained during the previous LPRM calibrations.
3/4.3.7.8 CHLORINE DETECTION SYSTEM DELETED 3/4.3.7.9 FIRE DETECTION INSTRUMENTATION OPERABILITY of the detection instrument'ation ensures that both adequate warning capability is available for the prompt detection of fires and that fire suppression systems, that are actuated by fire detectors, will discharge
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extinguishing agent in a timely manner. Prompt detection and suppression of fires will reduce the potential for damage to safety-related equipment and is an integral element in the overall facility fire protection program.
In the event that a. portion of the fire detection instrumentation is inoperable, increasing the frequency of fire watch patrols in the affected area (s), or zone (s), is required to provide detection capability until the inoperable instrumentation is restored to OPERABILITY.
GRAND GULF-UNIT 1 B 3/4 3-5 Amendment No. 25 l
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INSTRUMENTATION BASES 3/4.3.7.10 LOOSE-PART DETECTION SYSTEM The OPERABILITY of the loose part detection system ensures that sufficient capability is'available to detect loose metallic parts in the primary system and avoid or mitigate damage to primary system components. The system consists of 16 sensors, of which only 8 are selected and need to be OPERABLE at a time, to provide the inputs to the 8 mohitoring channels. The remaining 8 sensors may be used as m placement sensor inputs for failed sensors or to provide a change in location of the area being monitored. The allowable out-of-service times and surveillance requirements are consistent with the recommendations of Regulatory Guide 1.133, " Loose-Part Detection Program for the Primary System of Light-Water-Cooled Reactors," May 1981.
3/4.3.7.11 RADIOACTIVE LIQUID EFFLUENT DONITORING INSTRUMENTATION The radioactive liquid effluent monitoring instrumentation is provided to monitor and control, as applicable, the releases of radioactive materials in liquid effluents during actual or potent'ial releases of liquid effluents. The alam/ trip setpoints for these instruments shall be calculated in accordance with the procedures in the ODCM to ensure that the alare/ trip will occur prior to exceeding the limits'of 10 CFR Part 20. The OPERABILITY and use of this instrumentation is consistent with the requirements of General Design Crit?ria 60, 63 and 64 of Appendix A to 10 CFR Part 50.
MWW 3/4.3.7.12 RADIOACTIVE GASECUS EFFLUENT MONITORING INSTRUMENTATION
,h The radioactive gaseous effluent monitoring instrumentation is provided to monitor and control, as applicable, gaseous effluents during actual or potential releases. Those instruments that monitor the activity.of gaseous effluents being released to the environment shall have their alare/ trip setpoints calculated in accordance with the methods in the ODCM to ensure that the alare/ trip will occur prior to exceeding the limits of 10 CFR Part 20.
Other instruments that monitor offgas processing, (i.e., the Explosive Gas Monitor, Offgas Pre-Treatment Monitor, and Offgas Post-Treatment Monitor) are calibrated according to plant procedures. The OPERABILITY and use of this instrumentation is consistent with the requirements of Geperal Design Criteria 60, 63 and 64 of Appendix A to 10 CFR Part 50.
i 3/4.3.8 PLANT SYSTEMS ACTUATION INSTRUMENTATION The plant systems actuation instrumentation is provided to initiate action to citigate the consequences of accidents that are beyond the ability of the operator to control. The LPCI mode of the RHR system is automatically initiated on a high drywell pressure signal and/or a low reactor water level, level 1. -
signal. The containment spray system will then actuate automatically following high drywell and high containment pressure signals. Negative barometric pressure fluctuations are accounted for in the trip setpoints and allowable values speci-fled for drywell and containment pressure-high. A 10-minute minimum, 13-minute maximum time delay exists between initiation of LPCI and containment spray cctuation. A high reactor water level, level 8, signal will actuate the feed-water system / main turbine trip system. The suppression pool makeup system is automatically initiated on a low low suppression pool water level signal with a concurrent LOCA signal or following a specified time delay after receipt of a LOCA signal. The low low suppression pool water level Trip Setpoint and Allowable Value are relative to the surface floor of the suppression pool (93'6" above mean sea level).
GRAND GULF-
'1 B 3/4 3-6 l
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