ML20215M103
| ML20215M103 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 10/22/1986 |
| From: | Butler W Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20215M107 | List: |
| References | |
| TAC-63003, NUDOCS 8610300035 | |
| Download: ML20215M103 (17) | |
Text
__
[f U Kicgo, UNITED STATES
(,',g NUCLEAR REGULATORY COMMISSION g
Mff E WASHINGTON, D. C. 20555
'+9
,o 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. 22 License No. NPF-29 1.
The Nuclear Regulatory Comission (the Commission) 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 October 3, 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 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; l
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 Commission'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. 22, 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.
8610300035 861022 PDR ADOCK 05000416 P
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This license amendrnent is effective as of October 3,1986.
FOR THE NUCLEAR REGULATORY COMMISSION orgpal signed by Walter R. Butler, Director BWR Project Directorate No. 4 Division of BWR Licensing
Attachment:
Changes to the Technical Specifications Date of Issuance: October 22, 1986 n /4 L
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This license amendment is effective as of October 3, 1986.
FOR THE NUCLEAR REGULATORY COMMISSION Walter R. Butler, Director RWR Pro.iect Directorate No. 4 Division of RWR Iicensing
Attachment:
Changes to the Technical Specifications Date of Issuance: October 22, 1986 e
I
ATTACHMENT TO LICENSE AMENDMENT NO. 22 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. Asterisk pages provided to mairitain document completeness.*
Remove Insert 3/4 3-9 3/4 3-9 3/4 3-9a 3/4 3-10 3/4 3-10*
3/4 6-27 3/4 6-27*
3/4 6-28 3/4 6-28 3/4 6-47 3/4 6-47*
3/4 6-48 3/4 6-48 3/4 6-48a 3/4 6-49 3/4 6-49 3/4 6-49a 3/4 6-50 3/4 6-50*
3/4 6-55 3/4 6-55 3/4 6-56 3/4 6-56*
INSTRUMENTATION 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2 The isolation actuation instrumentation channels shown in Table 3.3.2-1 shall be OPERABLE with their trip setpoints set consistent with the values ::hown in the Trip Setpoint column of Table 3.3.2-2 and with ISOLATION SYSTEM RESPONSE TIME as shown in Table 3.3.2-3.
APPLICABILITY: As shown in Table 3.3.2-1.#
g ACTION:
With an isolation actuation instrumentation channel trip setpoint a.
less conservative than the value shown in the Allowable Values column of Table 3.3.2-2, declare the channel inoperable until the channel l
is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint valu2.
b.
With the number of OPERABLE channels less than required by the Minimum i
OPERABLE Channels per Trip System requirement for one trip system, i
place the inoperable channel (s) and/or that trip system in the tripped condition
- within one hour. The provisions of Specification 3.0.4 are not applicable.
l c.
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement for both trip systems,
(
place at least one trip system ** in the tripped condition within one hour and take the ACTION required by Table 3.3.2-1.
SURVEILLANCE REQUIREMENTS j
4.3.2.1 Each isolation actuation instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and i
CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.2.1-1.
]
4.3.2.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of
=
j all channels shall be performed at least once per 18 months.
4.3.2.3 The ISOLATION SYSTEM RESPONSE TIME of each isolation trip function shown in Table 3.3.2-3 shall be demonstrated to be within its limit at least once per 18 months. Each test shall include at least one channel per trip system such that all channels are tested at least once every N times 18 months, where N is the total number of redundant channels in a specific isolation trip system.
"An inoperable channel need not be placed in the tripped condition where this would cause the Trip Function to occur. In these cases, the inoperable channel shall be restored to OPERA 8LE status within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or the ACTION required by j
Table 3.3.2-1 for that Trip Function shall be taken.
- The trip system need not be placed in the tripped condition if this would cause the Trip Function to occur. When a trip system can be placed in t5e tripped condition without causing the Trip Function to occur, place the trip system with the most inoperable channels in the tripped condition; if both j
systems have the same number of inoperable channels, place either trip system in the tripped condition.
GRAND GULF-UNIT 1 3/4 3-9 Amendment No. 22 l
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INSTRUMENTATION l
- Isolation actuation instrumentation is not required to be OPERABLE during control rod removal, reinstallation and movement within defueled core cells for the period from October 3,1986, through October 10, 1986.
GRAND GULF-UNIT 1 3/4 3-9a Amendment No. 22 l
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9 cs I ABI E 3. 3.2-1 z
150lAll0N,ACIVAll0N INSIRUM[NIAll0N q
VALVE GROUPS MINIMUM APPLICARIE OPERAIED BY OPERABLE CHANNELS OPERATIONAL TlIIP F6NCTl0N SIGNAL (a) PER 1 RIP SYS11M p )
CON 0lll0N_
ACll0N
-4 1.
P..lMARY CONTAllet[Mi 1501 All0N j
a.
Reactor Vessel Water level-Low Low, Level 2 6A, 7, 8, 10(CII 2
1, 2, 3 and #
20 l
b.
Reactor Vessel Water level-
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Low Low Level 2 (ECC5 -
I, Division 3) 68 4
1, 2, 3 and #
29 c.
Reactor Vessel Water level-Low Low Low, Level 1 (ECCS -
S "II*I 2
1, 2, 3 and #
29 I
Division 1 and Division 2) 7 d.
Drywell Pressure - High 6A, 7(c)(d) y 3,' 2, 3 20 R
e.
Drywell Pressure-High am (ECCS - Division 1 and y
Division 2)
S'"II I g
f.
Drywell Pressure-High 2
1, 2, 3 29 l
(ECCS - Divisinn 3) 6B 4
1, 2, 3 29 i
g.
Containment and Drywell Ventilation Exhaust 2 'I 1, 2, 3 and
- 21 I
Radiation - High High 7
ICIId) h.
Manual Initiation 6A, 7, 8, 10 2
1, 2, 3 and *#
22 2.
MAIN STEAM 1INE ISOLAll0N a.
Reactor Vessel Water level-Low Low Low, Level i I
2 1, 2, 3 20 b.
Main Steam Line III Radiation - High I, 10 2
1, 2, 3 23 c.
Main Steam Line Pressure - low I
2 1
24 d.
Main Steam line F low - liigh I
8 1, 2, 3 21 e.
Condenser Vacum - low I
2 1, 7,
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CONTAINMENT SYSTEMS SUPPRESSION POOL MAKEUP SYSTEM LIMITING CONDITION FOR'0PERATION 3.6.3.4 The suppression pool makeup system shall be OPERABLE.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.
- CTION
a.
With one suppression pool makeup line inoperable, restore the inoperable makeup line 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 SHUT-DOWN 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.
With the upper containment pool water level less than the limit, restore the water level to within the limit within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 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 />.
c.
With upper containment pool water temperature greater than the limit, restore the upper containment pool water temperature to within the limit within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 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 />.
SURVEILLANCE REQUIREMENTS 4.6.3.4 The suppression pool makeup system shall be demonstrated OPERABLE:
a.
At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by verifying the upper containment poo.
water:
=
1.
Level to be greater than or equal to 23'3" above the pool bottom in the dryer / separator storage area, and 2.
Temperature to be less than or equal to 125'F.
b.
At least once per 31 days by verifying that each valve, manual, power operated or automatic, in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position, and both refueling gates are in the stored position or are otherwise removed l
. from the upper containment pool, c.
At,least once per 18 months by performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence and verifying that each automatic
)
valve in the flow path actuates to its correct position. Actual i
makeup of water to the suppression pool may be excluded from this test.
GRAND GULF-UNIT 1 3/4 6-27
CONTAINMENT SYSTEMS 3/4.6.4 CONTAINMENT AND DRYWELL ISOLATION VALVES LIMITING CONDITION FOR OPERATION
~
3.6.4 The containsient and drywell isolation valves shown in Table 3.6.4-1 shall be OPERABLE with isolation times less than or equal to those shown in Table 3.6.4-1.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, #, and M.
l ACTION:
With one or more of the containment or drywell isolation valves shown in Table 3.6.4-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> either:
Restore the inoperable valve (s) to OPERABLE status, or a.
b.
Isolate each affected penetration by use of at least one deactivated automatic valve secured in the isolated position," or Isolate each affected penetration by use of at least one closed c.
manual valve or blind flange.*
Otherwise, 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 />.
l
- Isolation valves, except MSIVs, closed to satisfy these requirements may be reopened on an intermittent basis under administrative controls.
- Isolation valves shown in Table 3.6.4-1 are also required to be OPERABLE when their associated actuation instrumentation is required to be OPERABLE per Table 3.3.2-1.
NContainment and drywell isolation valves are not required to be OPERABLE during control rod removal, reinstallation and movement within defueled core cells for the period from October 3, 1986, through October 10, 1986.
GRAND GULF-UNIT 1 3/4 6-28 Amendment No. 22 w
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i CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.
Demonstrated OPERABLE:
1.
At reast on~ce per 31 days by:
a)
Cycling the vacuum breaker and associated isolation valve through at least one complete cycle of full travel.
b)
Verifying the position indicators OPERABLE by observing expected vacuum breaker and associated isolation valve movements during the cycling test.
2.
At least once per 18 months by:
a)
Verifying the pressure differential required to open the vacuum breaker, from the closed position, to be less than or equal to 1.0 psid, and,*
b)
Verifying the position indicators of the vacuum breaker and associated isolation valve OPERABLE by performance of CHANNEL CALIBRATIONS.
3.
By verifying the OPERABILITY of the isolation valve differential pressure actuation instrumentation with the opening setpoint of 0.0 to 1.0 psid for the drywell purge subsystems and -1.0 to 0.0 psid for the post-LOCA vacuum relief subsystems (Orywell minus Containment) by performance of a:
a)
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 />, b)
CHANNEL FUNCTIONAL TEST at least once per 31 days, and c)
CHANNEL CALIBRATION at least once per 18 months.
GRAND GULF-UNIT 1
.,3/4 6-47 Amendment No.21 l
i Effective Date:
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CONTAINMENT SYSTEMS 3/4.6.6 SECONDARY CONTAINMENT SECONDARY CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.6.1 SECONDARY CONTAINMENT INTEGRITY shall be maintained.
APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2, 3,
- and W.
ACTION:
Without SECONDARY CONTAINMENT INTEGRITY:
In OPERATIONAL CONDITION 1, 2 or 3, restore SECONDARY CONTAINMENT a.
INTEGRITY within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 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 />.
i b.
In Operational Condition
- , suspend handling of irradiated fuel in the primary or secondary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
Specification 3.0.3 are not applicable.
The provisions of SURVEILLANCE REQUIREMENTS 4.6.6.1 SECONDARY CONTAINMENT INTEGRITY shall be demonstrated by:
Verifying at least once per 31 days that:
a.
1.
All Auxiliary Building and Enclosure Building equipment hatches and blowout panels are closed and sealed.
2.
The door in each access to the Auxiliary Building and Enclosure Building is closed, except for routine entry and exit.
3.
All Auxiliary Building and Enclosure Building penetrations not capable of being closed by OPERABLE secondary containment automatic isolation dampers / valves and required to be closed during accident conditions are closed by valves, blind flanges, rupture discs or deactivated automatic dampers / valves secured in position.
b.
At least once per 18 months:
1 1.
Verifying that one standby gas treatment subsystem will draw down i
the secondary containment to greater than or equal to 0.25 inches of vacuum water gauge in less than or equal to 120 seconds, and
[
2.
Operating one standby gas treatment subsystem for one hour and maintaining greater thar, or equal to 0.266 inches of vacuum water gauge in the secondary containment at a flow rate not exceeding 4000 CFM.
"Wh n irradiated fuel is being handled in the primary or secondary containment and during CORE ALTERATIONS and operations with a potential for draining the r: actor vessel.
GRAND GULF-UNIT 1 3/4 6-48 Amendment No. 22 l
l 4
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~
l CONTAINMENT SYSTEMS
- SECONCARY CONTAINMENT INTEGRITY is not required during control rod removal, reinstallation and movement within defueled core cells for the period from October 3,1986, through October 10, 1986.
GRAND GULF-UNIT 1 3/4 6-48a Amendment No. 22 u.
CONTAINMENT SYSTEMS SECONDARY CONTAINMENT AUTOMATIC ISOLATION DAMPERS / VALVES LIMITING CONDITION FOR OPERATION 3.6.6.2 Tis secondary containment ventilation system automatic isolation dampers / valves shown in Table 3.6.6.2-1 shall be OPERABLE with isolation times less than or equal to the times shown in Table 3.6.6.2-1.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3,
- and #.
l ACTION:
With one or more of the secondary containment ventilation system automatic isolation dampers / valves shown in Table 3.6.6.2-1 inoperable, maintain at least one isolation damper / valve OPERABLE in each affected penetration that is open, and within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> either:
Restore the inoperable damper / valve (s) to OPERABLE status, or a.
b.
Isolate each affected penetration by use of at least one deactivated automatic damper / valve secured in the isolation position, or Isolate each affected penetration by use of at least'one closed c.
manual valve or blind flange.
Otherwise, in OPERATIONAL CONDITION 1, 2 or 3, 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 />.
Otherwise, in Operational Condition
- , suspend handling of irradiated fuel in the primary or secondary containment, CORE ALTERATIONS and opera-tions with a potential for draining the reactor vessel. The provisions of Specification 3.0.3 are not applicable.
SURVEILLANCE REQUIREMENTS 1
4.6.6.2 Each secondary containment ventilation system automatic isolation damper / valve shown in Table 3.6.6.2-1 shall be demonstrated OPERABLE:
i Prior to returning the damper / valve to service after maintenance, repair a.
or replacement work is performed on the damper / valve or its associated actuator, control or power circuit by cycling the damper / valve through at least one complete cycle of full travel and verifying the specified isolation time.
b.
During COLD SHUTDOWN or REFUELING at least once per 18 months by verifying that on a containment isolation test signal each isolation damper / valve actuates to its isolation position.
By verifying the isolation time to be within its limit when tested c.
pursuant to Specification 4.0.5.
"When irradiated fuel is being handled in the primary or secondary containment and during CORE ALTERATIONS and operations with a potential for draining the 1
reactor vessel.
GRAND GULF-UNIT 1 3/4 6-49 Amendment No. 22 l
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CONTAINMENT SYSTEMS
- S:condary containment automatic isolation dampers / valves are not required to b2 OPERABLE during control rod removal, reinstallation and movement within defueled core cells for the period from October 3,1986, through October 10, 1986.
GRAND GULF-UNIT 1 3/4 6-49a Amendment No.22 l
TABLE 3.6.6.2-1 SECONDARY CONTAINMENT VENTILATION SYSTEM AUTOMATIC ISOLATION DAMPERS / VALVES MAXIMUM ISOLATION TIME DAMPER / VALVE FUNCTION, (Seconds) a.
Dampers Auxiliary Building Ventilation Supply Damper (Q1T41F006)-(B) 4 Auxiliary Building Ventilation Supply Damper (Q1T41F007)-(A) 4 Fuel Handling Area Ventilation Exhaust Damper (QlT42F003)-(B) 4 Fuel Handling Area Ventilation Exhaust Dameer (Q1T42F004)-(A) 4
~
Fuel Handling Area Ventilation Supply Damper (Q1T42F011)-(A) 4 Fuel Handling Area Ventilation Supply Damper (Q1T42F012)-(B) 4 Fuel Pool Sweep Ventilation Supply Damper (QlT42F019)-(A) 4 Fuel Pool Sweep Ventilation Supply Damper (Q1T42F020)-(B) 4 Containment & Drywell Area Ventilation Supply Damper 4
(Q1M41F007)-(B)
Containment & Drywell Area Ventilation Supply Damper 4
(Q1M41F008)-(A)
Containment & Drywell Area Ventilation Exhaust Damper 4
(Q1M41F036)-(A)
Containment & Drywell Area Ventilation Exhaust Damper 4
(QlM41F037)-(B)
The"-(A)ahd-(B)"designatorsonthevalve/dampernumbersindicateassociated electricalfivisions.
i CRAND Gt" F-UNIT 1 3/4 6-50 l
.4, CONTAINMENT SYSTEMS STANDBY GAS TREATMENT SYSTEM LIMITING CONDITION FOR OPERATION 3.6.6.3 Two independent standby gas treatment subsystems shall be OPERABLE.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3,
- and #.
ACTION:
With one standby gas treatment subsystem inoperable, restore the a.
inoperable subsystem to OPERABLE status within 7 days, or:
1.
In OPERATIONAL CONDITION 1, 2 or 3, 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.
In Operational Condition
- , suspend handling of irradiated fuel in the primary or secondary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
The provisions of Specification 3.0.3 are not applicable.
b.
With both standby gas treatment subsystems inoperable in Operational Condition *, suspend handling of irradiated fuel in the primary or secondary containment, CORE ALTERATIONS or operations with a potential for draining the reactor vessel. The provisions of Specification 3.0.3.
are not applicable.
SURVEILLANCE REQUIREMENTS 4.6.6.3 Each standby gas treatment subsystem shall be demonstrated OPERABLE:
At least once per 31 days by initiating, from the control room, flow a.
through the HEPA filters and charcoal adsorbers and verifying that the subsystem operates for at least 10. continuous hours with the heaters OPERABLE.
"When irradiated fuel is being handled in the primary or secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
- Standby gas treatment systems are not required to be OPERABLE during control rod removal, reinstallation and movement within defueled core cells for the period from October 3, 1986, through October 10, 1986.
GRAND GULF-UNIT 1 3/4 6-55 Amendment No.22 l
d CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.
At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating with the subsystem by:
1.
Verifying that the subsystem satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.S.a, C.S.c and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is 4000 cfm' i 10*..
2.
Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position 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.
3.
Verifying a subsystem flow rate of 4000 cfm t 10% during system operation when tested in accordance with ANSI N510-1975.
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 c.
within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Pegulatory 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.
l d
At least once per 18 months by:
1.
Performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence for the:
l a)
LOCA, and b)
Fuel handling accident.
2.
Verifying that the pressure drop across the combined H' EPA filters 1
I and charcoal adsorber banks is less than 9.2 inches Water Gauge while operating the filter train at a flow rate of 4000 cfm i 10%.
}
3.
Verifying that the filter train and isolation dampers receive the l
appropriate actuation signal by each of the following test conditions. For at least one of these test conditions, verify that the filter train starts and isolation dampers open on receipt of the actuation signal.
a.
Drywell pressure - high, b.
Reactor vessel water level - low low, level 2, Fuel handling area ventilation exhaust radiation - high high, c.
d.
Fuel handling area pool sweep exhaust radiation - high high, and e.
Manual initiation from the Control Room.
4'.
Verifying tnat the fan can be manually started.
5.
Verifying that the heaters dissipate 48 1 5.0 kW when tested l
in accordance with ANSI N510-1975 (except for the phase l
balance criteria stated in Section 14.2.3).
GRAND GULF-UNIT 1 3/4 6-56 Amendment No. _ll, l
,_ _