ML20206Q710
| ML20206Q710 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 08/27/1986 |
| From: | Butler W Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20206Q714 | List: |
| References | |
| TAC-61530, NUDOCS 8609050162 | |
| Download: ML20206Q710 (20) | |
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UNITED STATES NUCLEAR REGULATORY COMMISSION E
WASHINGTON, D. C. 20555 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 l
Amendment No.18 j
License No. NPF-29 1
The Nuclear Regulatory Commission (the Commission) has found that 1.
A.
The application for amendment by Mississippi Power & Light Company, Middle South Energy, Inc., and South Mississippi Electric Power Association, (the licensees) dated May 19, 1986 as supplemented by letters dated July 25 and July 29, 1986, 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 4
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 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, Facility Operating License NPF-29 is amended as follows:
A.
Change paragraph 2.C.(20) to read as follows:
(20) Standby Service Water System (Section 9.2.1 SER, SSER #2)
No irradiated fuel may be stored in the Unit I spent fuel storage l
pool prior to completion of modifications to either loop A or loop l
B of the standby service water (SSW) system and verification that the design flow can be achieved to all essential SSW sjstem com-ponents 1.n the modified-loop. However, should a core offloading be necessary prior to completion of these modifications (scheduled for the first refueling outage), irradiated fuel may be placed in the 8609050162 860827 PDR ADOCK 05000416 P-PDR w
. spent fuel pool when the RHR system operating in the spent fuel pool cooling mode is available. Until the SSW loops are modified, the spent fuel pool cooler in an unmodified loop shall be isolated from the loop by locked closed valves or the loop shall be declared inoperable. The position of these valves shall be verified every 31 days until the design flowrate for the SSW loop is demonstrated.
The surveillance to be performed is to verify that any unmodiffed SSW loop with valves which are not locked closed is declared inoperable.
3.
The license is further amended by changes to the Technical Specifi-cations as indicated in the attachment to this license arrendment, 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.18 are hereby incorporated into this license. Mississippi Power & Light Company shall operate the facility in accordance with the Technical Speci-fications and the Environmental Protection Plan.
4.
License Condition 2.C.(20) and Technical Specification Pages 1-3, 3/4 3-42, 3/4 7-2, and B 3/4 3-3 in this amendment are effective upon issuance of this amendment. Technical Specification Pages 3/4 3-29, 3/4 3-32a, 3/4 3-35, 3/4 8-6 and 3/4 8-12 are effective when the equipment necessitating the changes on these Technical Specification pages is installed and made operable.
FOR THE NUCLEAR REGULATORY COMMISSION Walter R.' Butler, Director BWR Project Directorate No. 4 Division of BWR Licensing
Attachment:
Changes to the Technical Specifications Date of Issuance: August 27, 1986 V
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ATTACHMENT TO LICENSE AMENDMENT NO. 18 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 page(s) provided to maintain document completeness.*
Remove Insert 1-3 1-3 1-4 1-4*
3/4 3-29 3/4 3-29 3/4 3-30 3/4 3-30*
3/4 3-32a 3/4 3-35 3/4 3-35 3/4 3-36 3/4 3-36*
3/4 3-41 3/4 3-41*
3/4 3-42 3/4 3-42 3/4 7-1 3/4 7-1*
3/4 7-2 3/4 7-2 3/4 8-5 3/4 8-5*
3/4 8-6 3/4 8-6 3/4 8-11 3/4 8-11*
3/4 8-12 3/4 8-12 B 3/4 3-3 B 3/4 3-3 8 3/4 3-3a B 3/4 3-3a*
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DEFINITIONS E-AVERAGE DISINTEGRATION ENERGY 1.11 E shall be the average, weighted in proportion to the concentration of each radionuclide in the reactor coolant at the time of sampling, of the sum of the average beta and gamma energies per disintegration, in MeV, for isotopes, with half lives greater than 15 minutes, making up at least 95% of the total non-iodine activity in the coolant.
EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME i
1.12 The EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ECCS actuation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function, i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc. Times shall include diesel generator starting and sequence loading delays where applicable. The i
response time may be measured by any series of sequential, overlapping or total steps such that the entire response time is measured.
END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME 1.13 The END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME shall be that time interval to complete suppression of the electric arc between the w
fully open contacts of the recirculation pump circuit breaker from initial movement of the associated:
a.
Turbine stop valves, and b.
Turbine control valves.
The response time may be measured by any series of sequential, overlapping or total steps such that the entire response time is measured, except for the breaker arc suppression time which is not measured but is validated by sur-veillance tests to conform to the manufacturer's design value.
FRACTION OF LIMITING POWER DENSITY 1.14 The FRACTION OF LIMITING POWER DENSITY (FLPD) shall be the LHGR existing j
at a given location divided by the limiting LHGR for that bundle type.
FRACTION OF RATED THERMAL POWER l
1.15 The FRACTION OF RATED THERMAL POWER (FRTP) shall be the measured THERMAL POWER divided by the RATED THERMAL POWER.
l FREQUENCY NOTATION 1.16 The FREQUENCY NOTATION specified for the performance of Surveillance Requirements shall correspond to the intervals defined in Table 1.1.
GASEOUS RADWASTE TREATMENT (0FFGAS) SYSTEM l
1.17 The GASEOUS RADWASTE TREATMENT (OFFGAS) SYSTEM is the system designed and installed to reduce radioactive gaseous effluents by collecting primary coolant system offgases from the primary system and providing for delay or holdup for the j
purpose of reducing the total radioactivity prior to release to the environment.
GRAND GULF-UNIT 1 1-3 Amendment No.18 l
INSTRUMENTATION BASES 3/4.3.6 CONTROL ROD BLOCK INSTRUMENTATION The control rod block functions are provided consistent with the require-ments of the specifications in Section 3/4.1.4, Control Rod Program Controls and Section 3/4.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.
The OPERABILITY of the control rod block instrumentation in OPERATIONAL CONDITION 5 is to provide diversity of rod block protection to the one-rod-out interlock.
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GRAND GULF-UNIT 1 B 3/4 3-3a Amendment No. 16
TABLE 3.3.3-1 (Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION h
MINIMUM OPERABLE APPLICABLE 8
CHANNELS PER OPERATIONAL 1
TRIP FUNCTION TRIP FUNCTION (a)
CONDITIONS ACTION g
5 C.
DIVISION 3 TRIP SYSTEM e
?!
HPCS SYSTEM
)
a.
Reactor Vessel Water Level - Low, Low, level 2 4
1, 2, 3, 4*, 5*
33 I
b.
Drywell Pressure - High##
4 1,2,3 33 c.
Reactor Vessel Water Levcl-High, level 8 2
1, 2, 3, 4*, 5*
31 4
)
d.
Condensate Storage Tank Level-Low 2
1, 2, 3, 4*, 5*
34 e.
Suppression Pool Water level-High 2(d) 1, 2, 3, 4*, 5*
34 i
f.
Manual Initiation ##
1 1, 2, 3, 4*, 5*
32 D.
LOSS OF POWER 1.
Division 1 and 2 I
a.
4.16 kV Bus Undervoltage 4
1, 2, 3, 4**, 5**
30 (Loss of Voltage) w 1
b.
4.16 kV Bus Undervoltage 4
1, 2, 3, 4**, 5**
30 I
(B0P Load Shed) w l
4 c.
4.16 kV Bus Undervoltage 4
1, 2, 3, 4**, 5**
30 l
(Degraded Voltage) 2.
Division 3 a.
4.16 kV Bus Undervoltage 4
1, 2, 3, 4**, 5**
30 (Loss of Voltage) b.
4.16 kV Bus Undervoltage 4
1, 2, 3, 4**, 5**
30 (Degraded Voltage)
(a) A channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> during periods of required surveillance without placing the trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.
(b) Also actuates the associated division diesel generator, mg (c) Provides signal to close HPCS pump discharge valve only.
3.
(d) Provides signal to HPCS pump suction valves only.
RR Applicable when the system is required to be OPERABLE per Specification 3.5.2 or 3.5.3.
Q Required when applicable ESF equipment is required to be OPERABLE.
%E Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 135 psig.
Prior to STARTUP following the first refueling outage, the injection function of Drywell Pressure -
gz
- P High and Manual Initiation are not required to be OPERABLE with indicated reactor vessel water level on the wide range instrument greater than Level 8 setpoint coincident with the reactor pressure less than 600 psig.
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ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
-d.
At least once per 18 months, during shutdown, by verifying that either:
1.
The battery capacity is adequate to supply and maintain in OPERABLE status all of the actual emergency loads for 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for Divi-sions 1 and 2 and 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for Division 3 when the battery is subjected to a battery service test, or 2.
The battery capacity is adequate to supply a dummy load of the following profile, which is verified to be greater than the actual emergency load, while maintaining the battery terminal voltage greater than or equal to 105 volts.
a)
Division 1
>950 amperes for the first 60 seconds F228 amperes for the next 119 minutes F399 amperes for the next 60 seconds b
F228 amperes for the next 118 minutes 7416 amperes for the last 60 seconds b)
Division 2
>462 amperes for the first 60 seconds F221 amperes for the next 119 minutes F392 amperes for the next 60 seconds F221 amperes for the next 118 minutes F278 amperes for the last 60 seconds c)
Division 3
>76 amperes for the first 60 seconds l
?
F16 amperes for the next 59 minutes F_18 amperes for the last 60~ minutes At least once per 60 months during shutdown by verifying that the e.
battery capacity is at least 80% of the manufacturer's rating when i
subjected to a performance discharge test. Once per 60 month interval, this performance discharge test may be performed in lieu of the battery service test.
f.
Annual performance discharge tests of battery capacity shall be given to any battery that shows signs of degradation or has reached 85% of the service life expected for the application. Degradation is indicated when the battery capacity drops more than 10% of rated capacity from its average on previous performance tests, or is below 90% of the manufacturer s rating.
GRAND GULF-UNIT 1 3/4 8-12 Amendment No.18 l
Effective Date:
s.
O TABLE 3.3.3-2 (Continued) c3 E!!
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS c,
SE ALLOWABLE l'
TRIP FUNCTION TRIP SETPOINT VALUE E::
D.
LOSS OF POWER (Continued) 2.
Division 3 (Continued) b.
4.16 kV Bus Underboltage 1.
4.16 kV Basis 3661 1 102.5 volts (Degraded Voltage) 3661 volts 2.
120 volt Basis 104.6 1 2.93 volts 104.6 volts 3.
Time Delay 5 minutes /No LOCA 5 minutes i 30 seconds 4 seconds /LOCA (4.0 1 0.4 seconds)
M.
YM 7, 's 7*
c.
co J
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-l ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 9.
Verifying the diesel generator operates for at least 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Diesel generators 11 and 12 shall be loaded to greater than or equal to 5450 kW but not to exceed 5740 kW for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Diesel generator 13 shall be loaded to greater than or equal to 3630 kW for the first 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> of this test and to 3300 kW during the remaining 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br />.
The generator voltage and frequency shall be 4.160 t 416 volts and 60 1 1.2 Hz within 10 seconds after the start signal; the steady state generator voltage and frequency shall be maintained within these limits during this test. Within 5 minutes after completing this 24-hour test, perform Surveillance Requirement 4.8.1.1.2.d.7.a).2) and b).2)*.
10.
Verifying that the auto-connected loads to each diesel generator do not exceed 5740 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13.
11.
Verifying the diesel generator's capability to:
a)
Synchror.ize with the offsite power source while the generator is loaded with its emergency loads upon a simulated restora-tion of offsite power, b)
Transfer its loads to the offsite power source, and c)
Be restored to its standby status.
12.
Verifying that with the diesel generator operating in a test mode and connected to its bus that a simulated ECCS actuation signal overrides the test mode by returning the diesel generator to standby operation.
13.
[ DELETED) 14.
[ DELETED]
i 15.
Verifying that the automatic load sequence timer is OPERABLE l
with the interval between each load block within i 10% of its I
design interval for diesel generators 11 and 12.
i
- If Surveillance Requirement 4.8.1.1.2.d.7.a)2) or b)2) are not satisfactorily completed, it is not necessary to repeat the preceding 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> test.
- Instead,
(
the diesel generator may be operated at the load specified by Surveillance Requirement 4.8.1.1.2.a.5 for one hour or until operating temperatures have stabilized.
(
GRAND GULF-UNIT 1 3/4 8-6 Amendment No.18 l
Effective Date:
TABLE 4.3.3.1-1 (Continued) m g
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH G;
TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED d.
B.
DIVISION 2 TRIP SYSTEM (Continued) 5 2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "B"#
a.
Low Low Low, level 1 S
M R(a) 1, 2, 3 b.
Drywell Pressure-High 5
M R(a) 1, 2, 3 c.
ADS Timer NA M
Q 1, 2, 3 d.
Low, Level 3
-S
--M-R(a)- - - 1. 2, 3 -
e.
LPCI Pump B and C Discharge Pressure-High 5
M(b)
R(,)
1,2,3 f.
Manual Initiation NA R
NA 1, 2, 3 C.
DIVISION 3 TRIP SYSTEM w1 1.
HPCS SYSTEM w
a.
J, Low Low, Level 2 S
M R(a) 1, 2, 3, 4*, 5*
R(a) 1, 2, 3 a
b.
Drywell Pressure-High##
5 M
R( )
1, 2, 3, 4*, 5*
c.
Reactor Vessel Water S
M Level-High, Level 8 d.
Condensate Storage Tank R,)
1, 2, 3, 4*, 5*
I Level - Low 5
M e.
Suppression Pool Wat.er Ia)
Level - High S
M(b)
R 1, 2, 3, 4*, 5*
f.
Manual Initiation ##
NA R
NA 1, 2, 3, 4*, 5*
D.
LOSS OF POWER 1.
Division 1 and 2 a.
4.16 kV Bus Undervoltage NA M(')
R 1, 2, 3, 4**, 5**
(Loss of Voltage)
IM ')-
R 1, 2, 3, 4**, 5**
m b.
4.16 kV Bus Undervoltage NA N
(B0P Load Shed)
IM ')
R 1, 2, 3, 4**, 5**
Ea c.
4.16 kV Bus Undervoltage NA pg (Degraded Voltage)
=a 2.
Division 3 g2 a.
4.16 kV Bus Undervoltage NA NA R
1, 2, 3, 4**, 5**
- P (Loss of Voltage) b.
4.16 kV Bus Undervoltage NA NA R
1, 2, 3, 4**, 5**
(Degraded Voltage)
PLANT SYSTEMS LIMITING CONDITION FOR OPERATION ACTION: (Continued) d.
In OPERATIONAL CONDITION 5 with the SSW subsystem, which is associated with an RHR system required OPERABLE by Specification 3.9.11.1 or 3.9.11.2, inoperable, declare the associated RHR system inoperable and take the ACTION required by Specification 3.9.11.1 or 3.9.11.2, as applicable.
In OPERATIONAL CONDITION *, with the SSW subsystem, which is associated e.
with a diesel generator required OPERABLE by Specification 3.8.1.2, inoperable, declare the associated diesel generator inoperable and take the ACTION required by Specification 3.8.1.2.
The provisions of Specification 3.0.3 are not applicable.
f.
In OPERATIONAL CONDITIONS 1, 2, 3, 4, or 5 with the SSW subsystem, which is associated with a diesel generator required OPERABLE by Specification 3.8.1.1 or 3.8.1.2, inoperable, declare the associated diesel generator inoperable and take the ACTION required by Specification 3.8.1.1 or 3.8.1.2 as applicable.
n SURVEILLANCE REQUIREMENTS 4.7.1.1 At least the above required standby service water system subsystem (s) shall be demonstrated OPERABLE:
At least once per 31 days by verifying that each valve in the flow a.
path that is not locked, sealed or otherwise secured in position, is in its correct position.
b.
At least once per 18 months during shutdown by verifying that each
~
automatic valve servicing safety related equipment actuates to its correct position on an actuation test signal.
l t
l GRAND GULF-UNIT 1 3/4 7-2 Amendment No.18 s--
INSTRUMENTATION END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.4.2 The end-of-cycle recirculation pump trip (EOC-RPT) system instrumentation channels shown in Table 3.3.4.2-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.4.2-2 'and with the END-OF-CYCLE RECIRCULATION PUMP. TRIP SYSTEM RESPONSE TIME as shown in Table 3.3.4.2-3.
APPLICABILITY: OPERATIONAL CONDITION 1, when THERMAL POWER is greater than or equal to 40% of RATED THERMAL POWER.
ACTION:
With an end of-cycle recirculation pump trip system instrumentation a.
channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.4.2-2, declare the channel inoperable until the channel is restored to OPERABLE status with the channel setpoint adjusted consistent with the Trip Setpoint value.
a.
b.
With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels per Trip System requirement for one or both trip systems, place the inoperable channel (s) in the tripped condition within one hour.
With the number of OPERABLE channels two or rore less than required c.
by the Minimum OPERABLE Channels per Trip System requirement for one trip system and:
1.
If the inoperable channels consist of one turbine control valve channel and one turbine stop valve channel, place both inoperable channels in the tripped condition within one hour.
2.
If the inoperable channels include two turbine control valve channels or two turbine stop valve channels, declare the trip system inoperable.
d.
With one trip system inoperable, restore the inoperable trip 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 reduce THERMAL POWER to less than 40% of RATED THERMAL POWER within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
With both trip systems inoperable, restore at least one trip system e.
to OPERABLE status within one hour or reduce THERMAL POWER to less than 40% of RATED THERMAL POWER within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
GRAND GULF-UNIT 1 3/4 3-41
INSTRUMENTATION SURVEILLANCE REQUIREMENTS 4.3.4.2.1 Each end-of-cycle recirculation pump trip system instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3.4.2.1-1.
4.3.4.2.2.
LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.
4.3.4.2.3 The END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME of each trip function shown in Table 3.3.4.2-3 shall be demonstrated to be within its limit at least once per 18 months.
Each test shall include two turbine control valve channels from one trip system and two turbine stop valve channels from the other trip system such that all channels are tested at least once per 36 months.
The time required for Breaker Interruption
- shall be verified at least once per 60 months and added to the 18 month trip system times to verify that the overall END-OF-CYCLE RECIRCULATION PUMP TRIP RESPONSE TIME is within its limit.
o i
- Breaker Interruption time is defined as Breaker Response time plus Arc Suppression time. Breaker Response is the time from application of voltage to the trip coil until the main contacts separate. Arc Suppression is the time from main contact separation until the complete suppression of the electrical arc across the open contacts. Breaker Response shall be verified by testing and added to the manufacturer's design Arc Suppression time of 12 ms to deter-mine Breaker Interruption time. The breaker arc suppression time shall be validated by the performance of periodic contact gap measurements and high potential tests on the breaker vacuum interrupters in accordance with plant procedures.
GRAND GULF-UNIT 1 3/4 3-42 Amendment No.18
3/4.7 PLANT SYSTEMS 3/4.7.1 SERVICE WATER SYSTEMS STANDBY SERVICE WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.1 Each of the following independent standby service water (SSW) system subsystems shall be OPERABLE with each subsystem comprised of:
One'0PERABLE SSW pump, and a.
b.
An OPERABLE flow path capable of taking suction from the associated SSW cooling tower basin and transferring the water through the RHR heat exchangers and to associated plant equipment, as required, shall be OPERABLE as follows:
1.
In OPERATIONAL CONDITIONS 1, 2, and 3:
two subsystems; and 2.
In OPERATIONAL CONDITIONS 4, 5, and *:
the subsystems associated with the systems and components required to be OPERABLE by Specifications 3.4.9.2, 3.5.2, 3.8.1.2, 3.9.11.1 or 3.9.11.2.
APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2, 3, 4, 5 and *.
ACTION:
a.
In OPERATIONAL CONDITION 1, 2 or 3:
1.
With one SSW subsystem inoperable, restore the inoperable sub-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 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 /> 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 />.
2.
With both SSW subsystems inoperable, 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 /> 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 3 or 4 with the SSW subsystem, which is asso-ciated with an RHR loop required OPERABLE by Specification 3.4.9.1 t
or 3.4.9.2, inoperable, declare the associated RHR loop inoperable and take the ACTION required by Specification 3.4.9.1 or 3.4.9.2, as applicable, c.
In OPERATIONAL CONDITION 4 or 5 with the SSW subsystem, which is asso-ciated with an ECCS pump required OPERABLE by Specification 3.5.2, inoperable, declare the associated ECCS pump inoperable and take the ACTION required by Specification 3.5.2.
When handling irradiated fuel in the primary or secondary containment.
Whenever both SSW subsystems are inoperable, if unable to attain COLD SHUTDOWN as required by this ACTION, maintain reactor coolant temperature as low as practical by use of alternate heat removal methods.
GRAND GULF-UNIT 1 3/4 7-1
l TABLE 4.3.3.1-1 (Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS NOTATION i
i Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 135 psig.
Prior to STARTUP following the first refueling outage, the injection func-tion of Drywell Pressure - High and Manual Initiation are not required to tu OPERABLE with indicated reactor vessel water level on the wide range t
instrument greater than Level 8 setpoint coincident with the reactor pres-sure less than 600 psig.
Applicable when the system is required to be OPERABLE per Specification 3.5.2 or 3.5.3.
Required when ESF equipment is required to be OPERABLE.
(a) Calibrate trip unit at least once per 31 days.
(b) Manual initiation switches shal,1 be tested at least once per 18 months 1
during shutdown. All other circuitry associated with manual initiation shall receive a CHANNEL FUNCTIONAL TEST at least once per 31 days as a part of circuitry required to be tested for automatic system actuation.
(c) DELETED (d) DELETED (e) Functional Testing of Time Delay Not Required l
3 l
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6 i
l l
t i
i 1
l 6
f GRAND GULF-UNIT 1 3/4 3-36
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ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 5.
Verifying that on an ECCS actuation test signal, without loss of offsite power, the diesel generator starts on the auto-start signal and operates on standby for greater than or equal to 5 minutes.
The generator voltage and frequency shall be 4160 1 416 volts and 60 1 1.2 Hz within 10 seconds after the auto-start signal; the steady state generator voltage and frequency shall be maintained within these limits during this test.
6.~
[0ELETED]
7.
Simulating a loss of offsite power in conjunction with an ECCS actuation test signal, and:
4 a), For Division 1 and 2:
1)
Verifying deenergization of the emergency busses and load shedding from the emergency busses.
2)
Verifying the diesel generator starts on the auto-start signal, energiz'es the emergency busses with permanently connected loads within 10 seconds, energizes the auto-connected shutdown loads through the load sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the emergency loads.
After energization, the steady state voltage and frequency of the emergency busses shall be maintained at 4160 1 416 volts and 6011.2 Hz during this test.
b)
For Division 3:
1)
Verifying de-energization of the emergency bus.
3 2)
Verifying the diesel generator starts on the auto-start signal, energizes the emergency bus with the permanently connected loads within 10 seconds and the autoconnected emergency loads within 20 seconds and operates for greater than or equal to 5 minutes while its generator is loaded with the emergency loads. After energization, the steady state voltage and frequency of the emergency bus shall be maintained at 4160 1 416 volts and 60 1 1.2 Hz during this test.
8.
Verifying that all automatic diesel generator trips are automatically bypassed upon an ECCS actuation signal except:
a)
For Divisions 1 and 2, engine overspeed, generator dif-forential current, and low lube oil pressure.
l b')
For Olvision 3, engine overspeed and generator differential current.
GRAND GULF-UNIT 1 3/4 8-5 Amendment No.
6
[
Effective Date:
ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS 4.8.2.1 Each of the above required 125-volt batteries and chargers shall be demonstrated OPERABLE:
At least once per 7 days by verifying that:
a.
1.
The parameters in Table 4.8.2.1-1 meet the Category A limits, and 2.
Total battery terminal voltage is greater than or equal to 129-volts on float charge.
b.
At least once per 92 days and within 7 days after a battery discharge with battery terminal voltage below 110-volts, or battery overcharge with battery terminal voltage above 150 volts, by verifying that:
1.
The parameters in Table 4.8.2.1-1 seet the Category B limits, 2.
There is no visible corrosion at either terminals or connectors, or the connection resistance of these items is less than 150 x 10 8 ohms, and 3.
The average electrolyte temperature of every sixth connected cells is above 60'F.
At least once per 18 months by verifying that:
c.
1.
The cells, cell plates and battery racks show no visual indication of physical damage or abnormal deterioration, 2.
The cell-to-cell and terminal connections are clean, tight, free of corrosion and coated with anti corrosion material, i
3.
The resistance of each cell and terminal connection is less than or equal to 150 x 10 8 ohms, and 4.
The battery charger will supply:
a)
For Divisions 1 and 2, at least 400 amperes at a minimum of 125 volts for at least 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />.
b)
For Division 3, at least 50 amperes at a minimum of 125 volts for at least 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
GRAND GULF-UNIT 1 3/4 8-11
INSTRUMENTATION TABLE 3.3.3-1 (Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION ACTION ACTION 30 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:
With one channel inoperable, place the inoperable channel a.
in the tripped condition within one hour
- or declare the associated system (s) inoperable.
b.
With more than one channel inoperable, declare the associated system (s) inoperable.
ACTION 31 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, declare the associated ADS trip system or ECCS inoperable.
ACTION 32 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, restore the inoperable channel to OPERABLE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or declare the assuciated ADS trip system or ECCS inoperable.
ACTION 33 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place the inoperable channel (s) in the tripped condition within one hour
- or declare the HPCS system inoperable.
ACTION 34 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place at least one inoperable channel in the tripped condition within one hour
- or declare the HPCS system inoperable.
"The provisions of Specification 3.0.4 are not applicable.
GRAND GULF-UNIT 1 3/4 3-30
+
INSTRUMENTATION BASES RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION (Continued) feature will function are closure of the turbine stop valves and fast closure j
of the turbine control valves.
A fast closure sensor from each of two turbine control valves provides input to the E0C-RPT system; a fast closure sensor from each of the other two turbine control valves provides input to the second EOC-RPT system.
Similarly, a closure sensor for each of two turbine stop valves provides input to one r
EOC-RPT system; a closure sensor from each of the other two stop valves provides input to the other EOC-RPT system.
For each EOC-RPT system, the sensor relay contacts are arranged to form a 2-out-of-2 logic for the fast closure of turbine control valves and a 2-out-of-2 logic for the turbine stop valves. The operation of either logic will actuate the EOC-RPT system and trip both recirculation pumps.
Each EOC-RPT system may be manually bypassed by use of a keyswitch which.is administratively controlled. The manual bypasses and the automatic Operating Bypass at less than 40% of RATED THERMAL POWER are annunciated in the control The automatic bypass setpoint is feedwater temperature dependent due to room.
the subcooling changes that affect the turbine first-stage pressure-reactor power relationship.
For RATED THERMAL POWER operation with feedwater tempera-ture greater than or equal to 420*F, an allowable setpoint of 1 26.9% of control valve wide open turbine first stage pressure is provided for the bypass func-tion. This setpoint is also applicable to operation at less than RATED THERMAL POWER with the correspondingly lower feedwater temperature.
The allowable setpoint is reduced to 5 22.5% of control valve wide open turbine first-stage pressure for RATED THERMAL POWER operation with a feedwater temperature between 370*F and 420*F.
Similarly, the reduced setpoint is applicable to operation at less than RATED THERMAL POWER with the correspondingly lower feedwater temperature.
The EOC-RPT system response time is the time assumed in the analysis 4
between initiation of valve motion and complete suppression of the electric arc, i.e., 190 ms.
Included in this time are: the response time of the sensor, the response time of the system logic and the breaker interruption time. Breaker i
l interruption time includes both breaker response time and the manufacturer's design arc suppression time of 12 ms.
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.
3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION The reactor core isolation cooling system actuation instrumentation is provided to initiate actions to assure adequate core cooling in the event of reactor isolation from its primary heat sink and the loss of feedwater flow to the reactor vessel without providing actuation of any of the emergency core cooling equipment.
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.
GRAND GULF-UNIT 1 B 3/4 3-3 Amendment No. 18 l
l DEFINITIONS J
IDENTIFIED LEAKAGE 1.18 IDENTIFIED LEAKAGE shall be:
i a.
Leakage into collection systems, such as pump seal or valve packing leaks, that is captured and conducted to a sump or collecting tank, or b.
Leakage into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the opera-tion of the leakage detection systems or not to be PRESSURE BOUNDARY LEAKAGE.
i ISOLATION SYSTEM RESPONSE TIME 1
1.19 The ISOLATION SYSTEM RESPONSE TIME shall be that time interval from when i.
the monitored parameter exceeds its isolation actuation setpoint at the channel sensor until the isolation valves travel to their required positions.
i Times shall include diesel generator starting and sequence loading delays where i
applicable.
The response time may be measured by any series of sequential, overlapping or total steps such that the entire response time is measured.
LIMITING CONTROL ROD PATTELN 1.20 A LIMITING CONTROL R0D PATTERN shall be a pattern which results in the core being on a thermal hydraulic limit, i.e., operating on a limiting value for APLHGR, LHGR, or MCPR.
LINEAR HEAT GENERATION RATE 1.21 LINEAR HEAT GENERATION RATE (LHGR) shall be the heat generation per unit length of fuel rod.
It is the integral of the heat flux over the heat transfer area associated with the unit length.
LOGIC SYSTEM FUNCTIONAL TEST 1.22 A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all logic components, o
i.e., all relays and contacts, all trip units, solid state logic elements, etc., of a logic circuit, from sensor through and including the actuated device, to verify OPERABILITY, The LOGIC SYSTEM FUNCTIONAL TEST may be performed by any series of sequential, overlapping or total system steps such that the entire logic system is tested.
MAXIMUM FRACTION OF LIMITING POWER DENSITY 1.23 The MAXIMUM FRACTION OF LIMITING POWER DENSITY (MFLPD) shall be the highest value of the FLPD which exists in the core.
MEMER(S) 0F THE PUBLIC 1.24 MEM ER(S) 0F THE PUBLIC shall include all persons who are not occupationally associated with the plant.
This category does not include employees of the utility, its contractors or vendors. Also excluded from this category are persons who enter the site to service equipment or to make deliv-eries. This category does include persons who use portions of the site for recreational, occupational or other purposes not associated with the plant.
GRAND GULF-UNIT 1 1-4
.