ML20080C299
| ML20080C299 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 08/08/1983 |
| From: | Schwencer A Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20080C303 | List: |
| References | |
| NUDOCS 8308190478 | |
| Download: ML20080C299 (58) | |
Text
_
t11SSISSIPPI POWER AND LIGilT COMPANY HIOULE SOUTH ENERGY, lhC.
SOUTH HISS 1551PPI LLECTRIC POKER ASSOCIATION DOCKET no.50-41b GRAND GULF HUCLt.AR STATION, UNIT 1 AMENDhENT TO FACILITY OPERATING LICENSE License 40. hPF-13 Amendnent No. 8 1.
The Nuclear Regulatory Comission (the Comission ce the NRC) has found that:
A.
The applications for the anendment filed by the Ptississippi Power and Light Company dated March 24,1983, April 7,1903, and April 25, 1983, June 9,1983, June 14,1983, June 23,1983, and June 29, 1983, comply with the standards and requirenents of the Atomic Energy Act of 1954, as amended (the Act), and the Connission's regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the applications, the provisions of the Act, and the regulations of the Comission; C.
There is reasonable assurance:
(i) that the activities authorized by this anendment 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 anendnent will not be inimical to the cornon defense and security or to the health and safety of the public; and E.
The issuance of this anendnent is in accordance with 10 CFR Part 51 of the Comission's regulations and all applicable requirenents have been satisfied.
2.
Accordingly, the license is amended as follows:
A.
Page changes to the Technical Specifications as indicated in the attachment to this license amendment and paragraph 2.C.(2) to read as follows:
(2) The Technical Specifications ccntained in Appendix A, as revised through Anendvent No. 8, and the Environnental Protection Plan contained in Appendix B, are hereby incorpoiated in the license.
The licensecs shall operate the facility in accordance with the Technical Specifications and the Environnental Protection Plan.
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FOR THE HUCLEAR REGULATORY COINISSION Originalsigned by A. Schwencer, Chief Licensing Branch No. 2 Division of Licensing Date of Issuance: August 8,19S3
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I ATTACHMENT TO LICENSE AMENDMENT NO. 8 FACILITY OPERATING LICENSE NO. NPF-13 DOCKET NO. 50-416 Replace the following page of the Appendix "A" Technical Specifications with the enclosed page. This, revised page is identified by Amendment number and contains a vertical line indicating the area of change.
REMOVE INSERT 2-4 2-4 3/4 1-5 3/4 1-5 3/4 2-5 3/4 2-5 3/4 3-11 3/4 3-11 3/4 3-14 3/4 3-14 3/4 3-15 3/4 3-15 3/4 3-16 3/4 3-16 3/4 3-17 3/4 3-17 3/4 3-28 3/4 3-28 3/4 3-29 3/4 3-29 3/4 3-30 3/4 3-30 3/4 3-31 3/4 3-31 3/4 3-32 3/4 3-32 3/4 3-33 3/4 3-33 3/4 3-41 3/4 3-41 3/4 3-56 3/4 3-56 3/4 3-57 3/4 3-57 3/4 3-95 3/4 3-95 3/4 4-18 3/4 4-18 3/4 5-9 3/4 5-9 3/4 6-5 3/4 6-5 3/4 6-6 3/4 6-6 3/4 6-7 3/4 6-7 3/4 6-15 3/4 6-15 3/4 6-16 3/4 6-16 3/4 6-21 3/4 6-21 3/4 6-22 3/4 6-22 3/4 6-45a 3/4 6-45a
2-REMOVE INSERT 3/4 6-54 3/4 6-54 3/4 6-58 3/4 6-58 3/4 7-4 3/4 7-4 3/4 7-6 3/4 7-6 3/4 7-16 3/4 7-16 3/4 7-26 3/4 7-26 3/4 7-45 3/4 8-1 3/4 8-1 3/4 8-3 3/4 8-3 3/4 8-6 3/4 8-6 3/4 8-13 3/4 8-13 3/4 8-21 3/4 8-21 3/4 8-40 3/4 8-40 3/4 8-41 3/4 8-41 3/4 8-42 3/4 8-42 3/4 8-43 3/4 8-43 3/4 8-44 3/4 8-44 3/4 8-45 3/4 8-45 3/4 8-45a 3/4 11-1 3/4 11-1 3/4 11-5 3/4 11-5 3/4 11-12 3/4 11-12 3/4 11-13 3/4 11-13 6-11 6-11 O
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REACTIVITY CONTROL SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 4.1.3.1.4 The scram discharge volume shall be determined OPERABLE by demonstrating:
a.
The scram discharge volume drain and ~ vent valves OPERABLE, when control rods are scram tested from a normal control rod configuration of less than or equal to 50% ROD DENSITY at least once per 18 months, by verifying that the drain and vent valves:
1.
Close within 30 seconds after receipt of a signal for control rods to scram, and 2.
Open when the scram signal is reset.
b.
Proper level sensor response by performance of a CHANNEL FUNCTIONAL TEST of the scram discharge volume scram and control rod block level instrumentation at least once per 31 days.
GRAND GULF-UNIT 1 3/4 1-5 Amendment No. 8
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POWER DISTRIBUTION LIMITS 3/4.2.2 APRM SETPOINTS LIMITING CONDITION FOR OPERATION 3.2.2 The APRM flow biased simulated thermal power-high scram trip setpoint (5) and flow biased neutron flux-upscale control rod block trip setpoint (SRB) shall be established according to the following relationships:
Trip Setpoint Allowable Value S 5 (0.66W + 48%)T S 1 (0.66W + 51%)T S
$ (0.66W + 42%)T S
$ (0.66W + 45%)T RB RB where:
S and S are in percent of RATED THERMAL POWER.
RB W = Loop recirculation flow as a percentage of the loop recirculation flow which produces a rated core flow of 112.5 million 1bs/hr.
T = Lowest value of the ratio of FRACTION OF RATED THERMAL POWER (FRTP) divided by the MAXIMUM FRACTION OF LIMITING POWER DENSITY (MFLPD).
T is always less than or equal to 1.0.
APPLICABILITY:
00ERATIONAL CONDITION 1, when THERMAL POWER is greater than or equal to 25% of RATED THERMAL POWER.
ACTION:
With the APRM flow biased simulated thermal power-high scram trip setpoint and/
or the flow biased neutron flux-upscale control rod block trip setpoint less i
conservative than the value shown in the allowable value-column for 5 or S asabovedetermined,initiatecorrectiveactionwithin15minutesandresthe, S and/or S to within the required limits
- within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or reduce THERMAL RR POWER to le5s than 25% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.2.2 The FRTP AND MFLPD for each class of fuel shall be determined, the value of T calculated, and the most recent actual APRM flow biased simulated thermal power-high scram and flow biased neutron flux-upscale control rod block trip setpoints verified to be within the above limits or adjusted, as required:
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 />, b.
Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after completion of a THERMAL POWER increase of at least 15% of RATED THERMAL POWER, and Initially and at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> when the reactor is operating c.
with MFLPD greater than or equal to FRTP.
With MFLPD greater than the FRTP during power ascension up to 90% of RATED THERMAL POWER, rather than adjusting the APRM setpoints, the APRM gain may be adjusted such that APRM readings are greater than or equal to 100% times MFLPD provided that the adjusted APRM reading does not exceed 100% of RATED THERMAL POWER, the required gain adjustment increment does not exceed 10% of RATED THERMAL POWER and a notice of adjustment is posted on the reactor control panel.
GRAND GULF-UNIT 1 3/4 2-5 Amendment No. 8 l
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INSTRUMENTATION TABLE 3.3.2-1 (Continued)
ISOLATION ACTUATION INSTRUMENTATION ACTION ACTION 20 -
Be in at least HOT SHUTDOWN within 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 next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
ACTION 21 -
Close the affected system isolation valve (s) within one hour or:
a.
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 />.
b.
In Operational Condition *, suspend CORE ALTERATIONS, handling of irradiated fuel in the containment and operations with a potential for draining the reactor vessel.
ACTION 22 Restore the manual initiation function to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-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 />.
ACTION 23 -
Be in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT SHUTDOWN within 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 next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
ACTION 24 Be in at least STARTUP within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
ACTION 25 -
Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within one hour.
ACTION 26 -
Restore the manual initiation function 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 close the affected system isolation valves within the next hour and declare the affected system inoperable.
ACTION 27 -
Close the affected system isolation valves within one hour and declare the affected system inoperable.
ACTION 28 -
Lock the affected system isolation valves closed within one hour and declare the affected system inoperable.
NOTES When handling irradiated fuel in the containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
During CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
(a) See Specification 3.6.4, Table 3.6.4-1 for valves in each valve group.
(b) 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 /> for required surveillance without placing the trip system in the tripped con-dition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.
(c) Also actuates the standby gas treatment system.
(d) Also actuates the control room emergency filtration system in the isolation mode of operation.
(e) Two upscale-Hi Hi, one upscale-Hi Hi and one downscale, or two downscale signals from the same trip system actuate the trip system and initiate isolation of the associated containment and drywell isolation valves.
(f) Also trips and isolates the mechanical vacuum pumps.
(g) A channel is OPERABLE if 2 of 4 instruments in that channel are OPERABLE.
(h) Also actuates secondary containment ventilation isolation dampers and valves per Table 3.6.6.2-1.
(i) Closes only RWCU system isolation valves G33-F001, G33-F004, and G33-F251.
(j) Actuates the Standby Gas Treatment System and isolates Auxiliary Building penetration of the ventilation systems within.he Auxiliary Building.
GRAND GULF-UNIT 1 3/4 3-14 Amendment No. 7, 8
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LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM a.
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AUTOMATIC DEPRESSURIZATION SYSTEM NA 4.
HIGH PRESSURE CORE SPRAY SYSTEM
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LOSS OF PCWER NA GRAND GULF-UNIT 1 3/4 3-30 Amendment No. 8
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EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS NOTATION Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 135 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 shall be tested at least once per 18 months 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) 11anual initiation test shall include verification of the OPERABILITY of the LPCS and LPCI injection valve interlocks.
(See Note 1) l (d) This calibration shall consist of the CHANNEL CALIBRATION of the LPCS and LPCI injection valve interlocks with the interlock setpoint verified to be
< 150 psig.
(See Note 1)
(e) Functional Testing of Time Delay Not Required Note 1:
Until restart after the first refueling outage, the requirements of (c) and (d) above do not apply.
GRAND GULF-UNIT 1 3/4 3-33 Amendment No. 8
TABLE 3.3.4.2-2 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM SETPOINTS TRIP ALLOWABLE TRIP FUNCTION SETPOINT VALUE 1.
Turbine Stop Valve - Closure
> 40 psig*
1 -37 psig 2.
Turbine Control Valve - Fast Closure
> 44.3 psig*
> 42 psig A
Initial setpoint.
Final setpoint to be determined during startup test program.
Any required change to this setpoint shall be submitted to the Commission within 90 days of test completion.
GRAND GULF-UNIT 1 3/4 3-41 Amendment No. 8
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TABLE 4.3.7.12-2 (Continuedl RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS TABLE NOTATION At all times.
During main condenser offgas treatment system operation.
During operation of the main condenser air ejector.
- SOURCE CHECK may be deferred to the next shutdown of greater than 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> duration if unable to be performed at the monthly interval due to inaccessibility because of being in a high radiation area.
- The sensor will be calibrated for mr/hr or cpm from the calibration standard.
The conversion to release rate will be performed during subsequent unit apera-tion, but within one week.
(1) The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway and cantrol room alarm annunciation occurs if any of the fo; lowing conditions exists:
1.
Instrument indicates measured levels above the alarm / trip setpoint.
2.
Circuit failure.
3.
Instrument indicates a downscale failure.
4.
Instrument controls not set in operate mode.
(2) The CHANNEL FUNCTIONAL TEST shall also demonstrate that control room alarm annuciation occurs if any of the following conditions exists:
1.
Instrument indicates measured levels above the alarm setpoint.
2.
Circuit failure.
3.
Instrument indicates a downscale failure.
4.
Instrument controls not set in operate mode.
(3) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS.
These standards shall permit calibrating the system over its intended measurement range.
For subsequent CHANNEL CA1IBRATION, sources that have been related to the initial calibration shall be used.
(4) The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:
1.
One volume percent hydrogen, balance nitrogen, and 2.
Four volume percent hydrogen, balance nitrogen.
GRAND GULF-UNIT 1 3/4 3-95 Amendment No. 8
REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued) 4.4.6.1.2 The reactor coolant system temperature and pressure shall be deter-mined to be to the right of the criticality limit line of Figure 3.4.6.1-1 curves C and C' within 15 minutes prior to the withdrawal of control rods to bring the reactor to criticality and at least once per 30 minutes during system heatup.
4.4.6.1.3 The reactor vessel material specimens shall be removed and examined to determine reactor pressure vessel fluence as a function of time and THERMAL POWER as required by 10 CFR 50, Appendix H in accordance with the schedule in Table 4.4.6.1.3-1.
The results of these fluence determinations shall be used to update the curves of Figure 3.4.6.1-1.
The adjusted reference temperature resulting from neutron irradiation shall be calculated based on the greater of the following:
a.
Actual shift in the RT f r materials in the capsules as defined by the NOT CVN impact test.
b.
Predicted shift in RT for plate C2594-2 and weld 627260/8322A27AE (heat / lot) as determi b by Regulatory Guide 1.99, " Effects of 'tesidual Elements on Predicted Radiation Damage to Reactor Vessel Materials".
4.4.6.1.4 The reactor vessel flange and head flange temperature shall be verified to be greater than or equal to 70 F:
In OPERATIONAL CONDITION 4 when reactor coolant system temperature a.
is:
1.
5 100 F, at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
2.
1 80 F, at least once per 30 minutes.
b.
Within 30 minutes prior to and at least once per 30 minutes during tensioning.of the reactor vessel head bolting studs.
GRAND GULF-UNIT 1 3/4 4-18 Amendment No. 8
EMERGENCY CORE COOLING SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)
ACTION: (Continued) c.
With one suppression pool water level instrumentation division inoperable, restore the inoperable division to OPERABLE status within 7 days or verify the suppression pool water level to be greater than or equal to 18'4-3/4" or 12'8", as applicable, at least once per 12 hou's by an alternate indicator, d.
With both suppression pool water level instrumentation divisions inoperable, restore at least one inoperable division 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 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 /> and verify the suppression poc' sater level to be greater than or equal to 18'4-3/4" or 12'8", " applicable, at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by at least one alternate 1.idicator.
SURVEILLANCE REQUIREMENTS 4.5.3.1 The suppression pool shall be determined OPERABLE by verifying:
a.
The water level to be greater than or equal to, as applicable:
1.
18'4-3/4" 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.
12'5" at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
b.
Two suppression pool water level instrumentation divisions, with 1 channel per division, OPERABLE with the low water level alarm setpoint > 18'5 " or 12'8", as applicable, by performance of a:
1.
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 18 months.
4.5.3.2 With the suppression pool level less than the above limit or drained in OPERATIONAL CONDITION 4 or 5*, at least once per 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />s:
a.
Verify the required conditions of Specification 3.5.3.b to be satisfied, or b.
Verify footnote conditions
- to be satisfied.
GRAND GULF-UNIT 1 3/4 5-9 Amendment No. 8
CONTAINMENT SYSTEMS CONTAINMENT AIR LOCKS LIMITING CONDITION FOR OPERATION 3.6.1.3 Each containment air lock shall be OPERABLE with:
Both doors closed except when the air lock is being used for normal a.
transit entry and exit through the containment, then at least one air lock door shall be closed, and b.
An overall air lock leakage rate of less than or equal to 2 scf per hour at P,, 11.5 psig.
APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2* and 3.
ACTION:
With one containment air lock door inoperable:
a.
1.
Maintain at least the OPERABLE air lock door closed and either restore the inoperable air lock door to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or lock the OPERABLE air lock door closed.
2.
Operation may then continue until performance of the next required overall air lock leakage test provided that the OPERABLE air lock door is verified to be locked closed at least once per 31 days.
3.
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 />.
4.
The provisions of Specification 3.0.4 are not applicable.
b.
With the containment air lock inoperable, except as a result of an inoperable air lock door, maintain at least one air lock door closed; restore the inoperable air lock to OPERABLE status 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 />.
With one containment air lock door inflatable seal system seal pressure l
c.
instrumentation channel inoperable, restore the inoperable channel to OPERABLE status within 7 days or verify the associated inflatable seal pressure to be > 60 psig at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
- See Special Test Exception 3.10.1.
GRAND GULF-UNIT 1 3/4 6-5 Amendment No. 8
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.1.3 Each containment air lock shall be demonstrated OPERABLE:
a.
Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each closing, except when the air lock is being used for multiple entries, then at least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, by verifying seal leakage rate less than or equal to 2 scf per hour when the gap between the door seals is pressurized to Pa, 11.5 psig.
b.
By conducting an overall air lock leakage test at P,,11.5 psig, and verifying that the overall air lock leakage rate is within its limit:
1.
At least once per 6 months #, and 2.
Prior to establishing PRIMARY CONTAINMENT INTEGRITY when maintenance has been performed on the air lock that could affect the air lock sealing capability.*
c.
At least once per 6 months by verifying that only one door in each air lock can be opened at a time.
d.
By verifying each airlock door inflatable seal system OPERABLE by:
1.
Demonstrating each of the two inflatable seal pressure instrumentation channels per airlock door OPERABLE by performance of a:
a)
CHANNEL FUNCTIONAL TEST at least once per 31 days, and b)
CHANNEL CALIBRATION at least once per 18 months, with a low pressure setpoint of > 60 psig.
2.
At least once per 7 days, verifying seal air flask pressure to be greater than or equal to 60 psig.
3.
At least once per 18 months, conducting a seal pneumatic system leak test and verifying that system pressure does not decay more than 2 psig from 90 psig within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
The provisions of Specification 4.G.2 are not applicable.
Exemption to Appendix J cf 10 CFR 50.
GRAND GULF-UNIT 1 3/4 6-6 Amendment No. 8
CONTAINMENT SYSTEMS MSIV LEAKAGE CONTROL SYSTEM LIMITING CONDITION FOR OPERATION 3.6.1.4 Two independent MSIV leakage control system (LCS) subsystems shall be OPERABLE.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
With one MSIV leakage control 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 /> 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 4.6.1.4 Each MSIV leakage control sy; tem subsystem shall be demonstrated OPERABLE:
a.
At least once per 31 days by verifyirg:
1.
Blower OPERABILITY by starting the blowers from the control room and operating the blowers for at least 15 minutes.
2.
Heater OPERABILITY by demonstrating electrical continuity of the heating element circuitry.
b.
During each COLD SHUTDOWN, if not performed within the previous 92 days, by cycling each motor operated valve through at least one complete cycle of full travel.
c.
At least once per 18 months by:
1.
Performance of a functional test which includes simulated actuation of the subsystem throughout its operating sequence, and verifying that each automatic valve actuates to its correct position, the blowers start and the heater draws 7.8 to 9.5 amperes per phase.
2.
Verifying that the blower developed at least the below required vacuum at the rated capacity.
1 a)
Inboard valves, 15" 1 " H O at 100 scfm.
2 b)
Outboard valves, 50" 1 2" H O at 200 scfm.
2 d.
By verifying the inboard flow, inboard and outboard pressure, and inboard temperature instrumentation to be OPERABLE by performance of a:
1.
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 18 months.
GRAND GULF-UNIT 1 3/4 6-7 Amendment No. 8
CONTAINMENT SYSTEMS DRYWELL AIR LOCKS LIMITING CONDITION FOR OPERATION 3.6.2.3 Each drywell air lock shall be OPERABLE with:
a.
Both doors closed except when the air lock is being used for normal transit entry and exit through the drywell, then at least one air lock door shall be closed, and b.
An overall air lock leakage rate of less than or equal to 2 scf per hour at P, 11.5 psig.
3 APPLICABILITY: OPERATIONAL CONDITIONS 1, 2* and 3.
ACTION:
a.
With one drywell air lock door inoperable:
1.
Maintain at least the OPERABLE air lock door closed and either restore the inoperable air lock door to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or lock the OPERABLE air lock door closed.
2.
Operation may then continue provided that the OPERABLE air lock door is verified to be locked closed at least once per 31 days.
3.
Otherwise, be in at least HOT SHUT 00WN 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 />.
4.
The provisions of Specification 3.0.4 are not applicable.
b.
With the drywell air lock inoperable, except as a result of an inoperable air lock door, maintain at least one air lock door closed; restore the inoperable air lock to OPERABLE status 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 />.
c.
With one drywell air lock door inflatable seal system seal pressure instrumentation channel inoperable, restore the inoperable channel to OPERABLE status within 7 days or verify the associated inflatable seal oressure to be > 60 psig at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
^See Special Test Exception 3.10.1.
GRAND GULF-UNIT 1 3/4 6-15 Amendment No. 8 l
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.2.3 Each drywell air lock shall be demonstrated OPERABLE:
a.
Within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> after each closing, except when the air lock is being used for multiple entries, then at least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, by verifying seal leakage rate less than or equal to 2 scf per hour when the gap between the door seals is pressurized to P,, 11.5 psig.
b.
At least once per 6 months by conducting an overall air lock leakage test at P,11.5 psig and by veriping that the overall air lock leakager$teiswithinitslimit.
c.
At least once per 6 months by verifying that only one door in each air lock can be opened at a time.
d.
By verifying each airlock door inflatable seal system OPERABLE by:
1.
Demonstrating each of the two inflatable seal pressure instrumentation channels per airlock door OPERABLE by performance of a:
a)
CHANNEL FUNCTIONAL TEST at least once per 31 days, and b)
CHANNEL CALIBRATION at least once per 18 months, with a low pressure setpoint of > 60 psig.
2.
At least once per 7 days verifying seal air flask pressure to be greater than or equal to 60 psig.
3.
At least once per 18 months, conducting a seal pneumatic system leak test and verifying that system pressure does not decay more than 2 psig from 90 psig within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
- The provisions of Specification 4.0.2 are not applicable.
GRAND GULF-UNIT 1 3/4 6-16 Amendment No. 8
CONTAINMENT SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)
ACTION:
(Continued)
With one suppression pool water level instrumentation division inoper-ableand/o c.
channel in any pair (s) of temperature instrumentation channels in the same sector inoperable, restore the inoperable channel (s) to OPERABLE status within 7 days or verify suppression pool water level and/or temperature to be within the limits at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
d.
With both suppression pool water level instrumentation divisions inoperable and/or with both suppression pool water temperature instrumer.tation channels in any pair (s) of temperature instru-mentation channels in the same sector inoperable, restore at least one inoperable water level division and at least one inoperable l
water ten:perature instrumentation channel in each pair of temperature instrumentation channels in the same sector 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 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 4.6.3.1 The suppression pool shall be demonstrated OPERABLE:
a.
By verifying the suppression pool water volume to be within the limits 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.
At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> in OPERATIONAL CONDITION 1 or 2 by verifying the suppression pool average water temperature to be less thJn or equal to 95 F, except:
1.
At least once per 5 minutes during testing which adds heat to the suppression pool, by verifying the suppression pool average water temperature less than or equal to 105 F.
2.
At least once per hour when suppression pool average water temperature is greater than or equal to 95 F, by verifying suppression pool average water temperature to be less than or equal to 110 F and THERMAL POWER less than or equal to 1% of RATED THERMAL POWER.
3.
At least once per 30 minutes following a scram with suppression pool average water temperature greater than or equal to 95 F, by verifying suppression pool average water temperature less than or equal to 120 F.
GRAND GULF-UNIT 1 3/4 6-21 Amendment No. 8 l
l CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued c.
By verifying two suppression pool water level instrumentation divisions, with I channel per division, and at least twelve suppression pool water temperature instrumentation channels, at least two channels in each suppression pool sector shown below in Table 4.6.3.1-1, OPERABLE by performance of a:
1.
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 18 months, with the water level and temperature alarm setpoint for:
1.
High water level i 18'9",
2.
Low water level > 18'5-1/2", and 3.
High water temperature 1 90 F.
GRAND GULF-UNIT 1 3/4 6-22 Amendment No. 8
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 3.
By verifying the OPERABILITY of the vacuum breaker isolation valve differential pressure actuation instrumentation with the opening setpoint of -1.0 to 0.0 psid (Drywell minus Containment) by performance of a:
a)
CHANNEL CHECK at least once por 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.
Note 1:
Until restart after the first refueling outage, the following requirements shall apply:
3.6.5 c.
With the position indicator of an OPERABLE drywell post-LOCA isolation valve for a vacuum breaker inoperable, verify the isolation valve to be closed 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 local indication. Otherwise declare the isolation valve inoperable.
4.6.5.b.1 b.
Verifying the position indicator for the vacuum breaker isolation valve OPERABLE by observing expected valve movement during the cycling test.
4.6.5.b.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 indicator for the vacuum breaker isolation valve OPERABLE by performance of a CHANNEL CALIBRATION.
GRAND GULF-UNIT 1 3/4 6-45a Amendment No. #, 7, 8 November 18, 1982
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.
At least once per 18 months or (1) af ter 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.S.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 10% during system operation when tested in accordance with ANSI N510-1975.
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 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.
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:
a)
LOCA, and b)
Fuel handling accident.
2.
Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 9.2 inches Water Gauge while operating the filter train at a flow rate of 4000 cfm 10%.
3.
Verifying that the filter train starts and isolation dampers open on each of the following test signals:
a.
Drywell pressure - high, b.
Reactor vessel water level - low low, level 2, c.
Fuel handling area ventilation exhaust radiation - high, and d.
Fuel handling area pool sweep exhaust radiation - high.
e.
Manual initiation from the Control Room.
4.
Verifying that the fan can be manually started.
5.
Verifying that the heaters dissipate 50 5.0 kW when tested in accordance with ANSI N510-1975.
GRAND GULF-UNIT 1 3/4 6-54 Amendment No. 8
CONTAINMENT SYSTEMS ORYWELL PURGE SYSTEM LIMITING CONDITION FOR OPERATION 3.6.7.3 Two independent drywell purge system subsystems shall be OPERABLE.
APPLICABILITY:
OPERATIONAL CONDITIONS 1 and 2.
ACTION:
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 />.
SURVEILLANCE REQUIREMENTS Continued 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 2.
Verifying that the system operates for at least 15 minutes.
b.
At least once per 18 months by:
1.
Verifying a subsystem flow rate of at least 1000 cfm during subsystem operation for at least 15 minutes.
2.
Verifying the pressure differential required to open the vacuum breakers on the drywell purge compressor discharge lines, from the closed position, to be less than or equal to 1.0 psid.
c.
Verifying the OPERABILITY of the drywell purge compressor discharge 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:
1.
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 18 months.
GRAND GULF-UNIT 1 3/4 6-58 Amendment No. 8
PLANT SYSTEMS ULTIMATE HEAT SINK LIMITING CONDITION FOR OPERATION 3.7.1.3 At least the following independent SSW cooling tower basins, each with:
a.
A minimum basin water level at or above elevation 130'3" Mean Sea Level, USGS datum, equivalent to an indicated level of > 87".
b.
Two OPERABLE cooling tower fans,#
shall be OPERABLE:
a.
In OPERATIONAL Condition 1, 2 and 3, two basins, b.
In OPERATIONAL Condition 4, 5 and *, the basins associated with systems and components required OPERABLE by Specifications 3.7.1.1 and 3.7.1.2.
APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2, 3, 4, 5 and *.
ACTION:
a.
In OPERATIONAL CONDITION 1, 2, 3, 4, 5 and
- with one SSW cooling tower basin inoperable, declare the associated SSW subsystem inoperable and, if applicable, declare the HPCS service water system inoperable, and take the ACTION required by Specifications 3.7.1.1 and 3.7.1.2, as applicable.
b.
In OPERATIONAL CONDITION 1, 2, 3, 4 or 5 with both SSW cooling tower basins inoperable, declare the SSW system and the HPCS service water system inoperable and take the ACTION required by Specifications 3.7.1.1 and 3.7.1.2.
c.
In Operational Condition
- with both SSW cooling tower basins inoperable, declare the SSW system inoperable and take the ACTION required by Specification 3.7.1.1.
The provisions of Specification 3.0.3 are not applicable.
SURVEILLANCE REQUIREMENTS 4.7.1.3 At least the above required SSW cooling tower basins shall be deter-mined OPERABLE at least once per:
a.
24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by verifying basin water level to be greater than or equal to 87".
b.
31 days by starting each SSW cooling tower fan from the control room and operating the fan for at least 15 minutes.
c.
18 months by verifying that each SSW cooling tower fan starts automatically when the associated SSW subsystem is started.
A When handling irradiated fuel in the Auxiliary Building or Enclosure Building.
- The basin cooling tower fans are not required to be OPERABLE for HPCS service water system OPERABILITY.
GRAND GULF-UNIT 1 3/4 7-4 Amendment No. 8
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.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%.
3.
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.
4.
Verifying a subsystem flow rate of 4000 cfm 10% during subsystem operation when tested in accordance with ANSI N510-1975.
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 Positon 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.
d.
At least once per 18 months by:
1.
Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 7.2 inches Water Gauge while operating the subsystem at a flow rate of 4000 cfm i 10%.
2.
Verifying that on each of the below isolation mode actuation test signals, the subsystem automatically switches to the isola-tion mode of operation and the isolation valves close within 4 seconds:
a)
High radiation in the outside air intake duct, b)
High chlorine concentration in the outside air intake duct, c)
High drywell pressure, and d)
Low reactor water level.
e)
Manual initiation from the Control Room.
3.
Verifying that the heaters dissipate 20.7 1 2.1 kW when tested in accordarce with ANSI N510-1975.
After each complete or partial replacement of a HEPA filter bank by e.
verifying that the HEPA filter banks remove greater than or equal to 99.95% of the D0P when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 4000 cfm 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 10%.
GRAND GULF-UNIT 1 3/4 7-6 Amendment No. 8
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i PLANT SYSTEMS 3/4.7.5 SEALED SOURCE CONTAMINATION LIMITING CONDITION FOR OPERATION 3.7.5 Each sealed source containing radioactive material either in excess of 100 microcuries of beta and/or gamma emitting material or 10 microcuries of alpha emitting material shall be free of greater than or equal to 0.005 microcuries of removable contamination.
APPLICABILITY:
At all times.
ACTION:
a.
With a sealed source having removable contamination in excess of the above limit, withdraw the sealed source from use and either:
1.
Decontaminate and repair the sealed source, or 2.
Dispose of the sealed source in accordance with Commission Regulations.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.7.5.1 Test Requirements - Each sealed source shall be tested for leakage and/or contamination by:
a.
The licensee, or b.
Other persons specifically authorized by the Commission or an Agreement State.
The test method shall have a detection sensitivity of at least 0.005 microcuries per test sample.
4.7.5.2 Test Frequencies - Each category of sealed sources, excluding startup sources and fission detectors previously subjected to core flux, shall be tested at the frequency described below.
a.
Sources in use - At least once per six months for all sealed sources containing radioactive material:
1.
With a half-life greater than 30 days, excluding Hydrogen 3, and 2.
In any form other than gas.
GRAND GULF-UNIT 1 3/4 7-26 Amendment No. 8 f
i l
___-._________._.________J
PLANT SYSTEMS 3/4.7.10 EMBANKMENT STABILITY LIMITING CONDITION FOR OPERATION 3.7.10 The downstream access road slope at Culvert No. 1 and the drainage basin slopes shall remain stable.
APPLICABILITY:
At all times.
ACTION:
If Culvert No. 1 has blockage exceeding 15% of its cross-sectional area, the Culvert shall be cleaned and the slope emban(ments verified to be stable.
SURVEILLANCE REQUIREMENTS 4.7.10 The downstrean access road slope at Culvert No. 1 and the drainage basin slopes shall be confirmed to be stable by:
a.
At least once per year, performing a visual inspection of the embankments and Culvert No. 1.
b.
At least once per five years, performing a five year survey to confirm no significant degradation to the base-line data.
Following the occurrence of earthquakes, hurricanes, tornados, or intense c.
local rainfalls, a visual inspection of the embankments and Culvert No.1 will be made.
If this special inspection reveals evidence of change, a survey will be performed to confirm no significant degradation to the base-line data.
GRAND GULF-UNIT 1 3/4 7-45 Amendment No. 8
I.
3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES A.C. SOURCES - OPERATING LIMITING CONDITION FOR OPERATION 3.8.1.1 As a minimum, the following A.C. electrical power sources shall be OPERABLE:
a.
Two physically independent circuits between the offsite transmission network and the onsite Class lE distribution system, and b.
Three separate and independent diesel generators, each with:
1.
Separate day fuei tanks containing a minimum of 220 gallons of fuel.
2.
A separate fuel storage system containing a minimum of:
a) 48,000 gallons of fuel each for diesel generators 11 and 12, and b) 39,000 gallons of fuel for diesel generator 13.
3.
A separate fuel transfer pump.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.
ACTION:
a.
With either one offsite circuit or diesel generator 11 or 12 of the above required A.C. electrical power sources inoperable, demonstrate the OPERABILITY of the remaining A.C. sources by performing Surveil-lance Requirements 4.8.1.1.1.a within one hour and 4.8.1.1.2.a.4, for one diesel generator at a time, within three hours and at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> therafter; restore at least two offsite circuits and diesel generators 11 and 12 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 />.
b.
With one offsite circuit and diesel generator 11 or 12 of the above required A.C. electrical power sources inoperable, demonstrate the OPERABILITY of the remaining A.C. sources by performing Surveillance Requirements 4.8.1.1.1.a within one hour and 4.8.1.1.2.a.4, for one diesel generator at at time, within two hours and at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter; restore at least one of the inoperable A.C.
sources to OPERABLE status within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> cr 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 />.
Restore at least two offsite circuits and diesel genera-tors 11 and 12 to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from time of initial loss 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 SHUTOOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
GRAND GULF-UNIT 1 3/4 8-1 Amendment No. 8
ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits between the offsite transmission network and the onsite Class 1E distribution system shall be:
a.
Determined OPERABLE at least once per 7 days by verifying correct breaker alignments and indicated power availability, and b.
Demonstrated OPERABLE at least once per 18 months during shutdown by manually transferring unit power supply from the normal circuit to the alternate circuit.
4.8.1.1.2 Each of the above required diesel generators shall be demonstrated OPERABLE:
a.
In accordance with the frequency specified in Table 4.8.1.1.2-1 on a STAGGERED TEST BASIS by:
1.
Verifying the fuel level in the day tank.
2.
Verifying the fuel level in the fuel storage tank.
3.
Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day tank.
4 Verifying the diesel starts from ambient condition and accelerates to at least 441 rpm for diesel generators 11 and 12 and 882 rpm for diesel generator 13 in less than or equal to 10 seconds.
The generator voltage and frequency shall be 4160 416 volts and 60 1 1.2 Hz within 10 seconds after the start signal.
The diesel generator shall be started for this test by using one of the following signals:
a)
Manual.
b)
Simulated loss of offsite power by itself.
c)
Simulated loss of offsite power in conjunction with an ESF actuatior. test signal.
d)
An ESF actuation test signal by itself.
5.
Verifying the diesel generator is synchronized, loaded to greater than or equal to 3500 kW for diesel generators 11 and 12 and 1650 kW for diesel generator 13 in less than or equal to 60 seconds, and operates with these loads for at least 60 minutes.
6.
Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.
7.
Verifying the pressure in all diesel generator air start receivers to be greater than or equal to:
a) 160 psig for diesel generator 11 and 12, and b) 175 psig for diesel generator 13.
b.
At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> by checking for and removing accumulated water from the day fuel tanks.
GRAND GULF-UNIT 1 3/4 8-3 Amendment No. 7, 8
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 />.
During 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, the diesel generator shall be loaded to greater than or equal to 7700 kW for diesel gen-erators 11 and 12 and 3630 kW for diesel generator 13 and during the remaining 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> of this test, the diesel generator shall be loaded to 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13.
The generator voltage and frequency shall be 4160 1 416 volts and 60 i 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 the continuous rating of 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13.
11.
Verifying the diesel generator's capability to:
a)
Synchronize with the offsite' power source while the generator is loaded with its emergency loads upon a simulated restoration 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:
a)
For Divisions 1 and 2, overrides the test mode by return-ing the diesel generator to standby operation.
b)
For Division 3, overrides the test mode by bypassing the diesel generator automatic trips per Surveillance Require-ment 4.8.1.1.2.d.8.b).
13.
Verifying that with all diesel generator air start receivers pressurized to less than or equal to 256 psig and the compres-sors secured, the diesel generator starts at least 5 times from ambient conditions and accelerates to at least 441 rpm for diesel generators 11 and 12 and 882 rpm for diesel generator 13 in less than or equal to 10 seconds.
A If Surveillance Requirement 4.8.1.1.2.d.4.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 rated load for one hour or until operating temperatures have stabilized.
GRAND GULF-UNIT 1 3/4 8-6 Amendment No. 7, 8
TABLE 4.8.2.1-1 BATTERY SURVEILLANCE REQUIREMENTS f1)
CATEGORY B(2)
CATEGORY A Parameter Limits for each Limits for each Allowable (3) designated pilot connected cell value for each cell connected cell Electrolyte
> Minimum level
> Minimum level Above top of Level indication mark, indication mark,
- plates, and < %" above and < " above and not maximum level maximum level overflowing indication mark indication mark Float Voltage
> 2.13 volts 1 2.13 volts (D)
> 2.07 volts Not more than
.020 below the average of all 1 1.190 connected cells Specifi 1 1.195 l
Gravity [a)
Average of all Average of all connected cells connected cells
> 1.200 1 1.190 (a) Corrected for electrolyte temperature and level.
(b) May be corrected for average electrolyte temperature.
(1) For any Category A parameter (s) outside the limit (s) shown, the battery may be considered OPERABLE provided that within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> all the Category B measurements are taken and found to be within their allowable values, and provided all Category A and B parameter (s) are restored to within limits within the next 6 days.
(2) For any Category B parameter (s) outside the limit (s) shown, the battery may be considered OPERABLE provided that the Category B parameters are within their allowable values and provided the Category B parameter (s) are restored to within limits within 7 days.
(3) Any Category B parameter not within its allowable value indicates an inoperable battery.
GRAND GULF-UNIT 1 3/4 8-13 Amendment No. 8
TABLE 3.8.4.1-1 PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES TRIP
RESPONSE
SYSTEM /
DEVICE NUMBER SETPOINT TIME COMPONENT AND LOCATION (Amperes)
(Cycles)
AFFECTED a.
6.9 kV Circuit Breakers 7200/45/110%f 252-1103-B 60 Reactor Recir. Pump 252-1103-C 7200/45/1 10%g 60 Pump B33C001A 252-1205-B 7200/45/1 10%g 60 Reactor Recir. Pump 252-1205-C 7200/45/1 10%
60 Pump B33C001B b.
480 VAC Molded Case Circuit Breakers 1.
Stored Energy Type SS3G3 TRIP
RESPONSE
BREAKER SETPOINT TIME SYSTEM / COMPONENT NUMBER (Amperes)
(Seconds)
AFFECTED 52-12202 1200 0.05 CONTAINMENT COOLING FILTER TRAIN HEATERS (N1M410002B-N) 52-12209 2000 0.05 CNTMT POLAR CRANE (Q1F13E001-N) 51-11502 1200 0.05 CNTMT CLG. FILTER TRAIll HEATER (N1M410002A-N) 52-15105 2000 0.05 DRYWELL PURGE COMPRESS.
(Q1E61C001A-A) 52-16204 2000 0.05 DRYWELL PURGE COMPRESS.
(Q1E61C001B-B) 52-16404 1200 0.05 HYDROGEN RECOMBINER (Q1E61C0038-B)
- Primary current /setpoint.
GRAND GULF-UNIT 1 3/4 8-21 Amendment No. 8 i
m.__
TABLE 3.8.4.2-1 MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (LON-TINUOUS) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (NO)
AFFECTED Q1E51F010-A Continuous RCIC System Q1E51F013-A Continuous RCIC System Q1E51FG19-A Continuous RCIC System Q1E51F022-A Continuous RCIC System Q1E51F031-A Continuous RCIC System Q1E51F045-A Contineous RCIC System Q1E51F046-A Continuous RCIC System Q1E51F059-A Contint ous RCIC System Q1E51F068-A Continuous RCIC System Valve on Turbine Q1E51C002 Continuous RCIC System l
Q1821F065A-A No Reactor Coolant System Q1821F0658-A No Reactor Coolant System Q1B21F098A-B No Reactor Coolant System Q1821F0988-B No Reactor Coolant System Q1B;1F098C-B No Reactor Coolant System Q1BE1F0980-8 No Reactor Coolant System Q1821F019 Continuous Reactor Coolant System Q1821F067A Continuous Reactor Coolant System Q1821F067B Continuous Reactor Coolant System Q1B21F067C Continuous Reactor Coolant System Q1821F067D Continuous Reactor Coolant System Q1821F016 Continuous Reactor Coolant System Q1821F147A Continuous MSL Drain Post LOCA Leak-age Control Q1821F147B Continuous MSL Drain Post LOCA Leak-age Control Q1833F019 Continuous Recirculation System Q1B33F020 Continuous Recirculation System Q1833F125 Continuous Recirculation System Q1833F126 Continuous Recirculation System Q1833F127 Continuous Recirculation System Q1833F128 Continuous Recirculation System Q1D23F591B Drywell Monitoring System Q1023F592A Drywell Monitoring System Q1023F5938 Drywell Monitoring System Q1D23F594A Drywell Monitoring System Q1E12F040 Continuous RHR System Q1E12F023 Continuous RHR System Q1E12F006A Continuous RHR System Q1E12F052A Continuous RHR System Q1E12F008 Continuous RHR System GRAND GULF-UNIT 1 3/4 8-40 Amendment No. 8 l
TABLE 3.8.4.2-1 (Continued)
MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (CON-TINUOUS) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (NO)
AFFECTED Q1E12F074A Continuous RHR System Q1E12F026A Continuous RHR System Q1E12F082A No RHR System Q1E12F082B No RHR System Q1E12F290A Continuous RHR System Q1E12F047A Continuous RHR System Q1E12F027A Continuous RHR System Q1E12F073A Continuous RHR System Q1E12F346 Continuous RHR System Q1E12F024A Continuous RHR System Q1E12F087A Continuous RHR System Q1E12F048A Continuous RHR System Q1E12F042A Continuous RHR System.
Q1E12F004A Continuous RHR System Q1E12F003A Continuous RHR System Q1E12F011A Continuous RHR System Q1E12F053A Continuous RHR System Q1E12F037A Continuous RHR System Q1E12F028A Continuous RHR System Q1E12F064A Continuous RHR System Q1E12F2908 Continuous RHR System Q1E12F004C Continuous RHR System Q1E12F021 Continuous RHR System Q1E12F064C Continuous RHR System Q1E12F042C Continuous RHR System Q1E12F0488 Continuous RHR System Q1E12F049 Continuous RHR System Q1E12F037B Continuous RHR System Q1E12F053B Continuous RHR System Q1E12F074B Continuous RHR System Q1E12F0428 Continuous RHR System Q1E12F0648 Continuous RHR System Q1E12F096 Continuous RHR System Q1E12F094 Continuous RHR System Q1E12F006B Continuous RHR System Q1E12F0118 Continuous RHR System Q1E12F052B Continuous RHR System Q1E12F0478 Continuous RHR System Q1E12F027B Continuous RHR System Q1E12F0048 Continuous RHR System Q1E12F087B Continuous RHR System Q1E12F003B Continuous RHR System Q1E12F0268 Continuous RHR System Q1E12F024B Continuous RHR System Q1E12F028B Continuous RHR System Q1E12F009 Continuous RHR System Q1E12F073B Continuous RHR System GRAND GULF-UNIT 1 3/4 8-41 Amendment No. 8 l
1
TABLE 3.8.4.2-1 (Continued)
MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (CON-TINUOUS) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (NO)
AFFECTED Q1C11F083 No CR0 Hydraulic System Q1C11F322 Continuous CRD Hydraulic System Q1C41F001A Continuous Standby Liquid Control Q1C41F001B Continuous Standby Liquid Control Q1E21F001 Continuous LPCS System Q1E21F011 Continuous LPCS System Q1E21F01z Continuous LPCS System Q1E21F005 Continuous LPCS System Q1E30F002A Continuous Suppression Pool Makeup System Q1E30F591A Suppression Pool Makeup System Q1E30F592A Suppression Pool Makeup System Q1E30F593A Suppression Pool Makeup System Q1E30F594A Suppression Pool Makeup System QlE30F001A Continuous Suppression Pool Makeup System Q1E30F001B Continuous Suppression Pool Makeup System Q1E30F002B Continuous Suppression Pool Makeup System Q1E30F591B Suppression Pool Makeup System Q1E30F5928 Suppression Pool Makeup System Q1E30F593B Suppression Pool Makeup System Q1E30F594B Suppression Pool Makeup System Q1E31F100A Continuous Fuel Pool Cooling and Cleanup System Q1E31F100B Continuous Fuel Pool Cooling and Cleanup System Q1E32F001A Continuous MSIV - LCS Q1E32F001E Continuous MSIV - LCS Q1E32F003A Continuous MSIV - LCS Q1E32F003E Continuous MSIV - LCS Q1E32F003J Continuous MSIV - LCS Q1E32F003N Continuous MSIV - LCS Q1E32F001J Continuous MSIV - LCS Q1E32F001N Continuous MSIV - LCS Q1E32F002A Continuous MSIV - LCS Q1E32F002E Continuous MSIV - LCS Q1E32F002J Continuous MSIV - LCS Q1E32F002N Continuous MSIV - LCS Q1E32F006 Continuous MSIV - LCS Q1E32F007 Continuous MSIV - LCS Q1E32F008 Continuous MSIV - LCS Q1E32F009 Continuous MSIV - LCS Q1E38F001A Continuous Feedwater LCS Q1E38F001B Continuous Feedwater LCS GRAND GULF-UNIT 1 3/4 8-42 Amendment No. 8
1 TABLE 3.8.4.2-1 (Continued)
MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (CON-TINU0US) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (NO)
AFFECTED Q1E51F064 Continuous RCIC System Q1E51F063 Continuous RCIC System Q1E51F076 Continuous RCIC System Q1E51F077 Continuous RCIC System Q1E51F078 Continuous RCIC System Q1E22F001 Continuous HPCS System Q1E22F004 Continuous HPCS' System Q1E22F010 Continuous HFCS Systen Q1E22F011 Continuous HPCS System Q1E22F012 Continuous HPCS System Q1E22F015 Continuous HPCS System' Q1E22F023 Continuous HPCS System Q1E61F595A Combustible Gas Control System Q1E61F596A Combustible Gas Control System Q1E61F597A Combustible Gas Control System Q1E61F598A Combustible Gas Control System Q1E61F595C Combust ible Gas Control System Q1E61F596C Combustible Gas Control System Q1E61F597C Combustible Gas Control System Q1E61F598C
- Combustible Gas Control System Q1E61F595B Ccmbustible Gas Centrol System Q1E61F5968 Combustible Gas Control System Q1E61F597B
. Combustible Gas Control System Q1E61F5988 Combustible Gas Control System Q1E61F595D Combustible Gas Control System Q1E61F596D Combustible-Gas Control System Q1E61F5970 Combustible Gas Control System Q1E61F598D Combustible Gas Control System Q1E61F003A Continuous Combustible Gas Control System Q1E61F005A Continuous Combustible Gas Control System Q1E61F003B Continuous Combustible Gas Control System Q1E61F005B Continuous Combustible Gas Control System Q1G33F251 Continuous RWCU System QIG33F253 Continuous RWCU System Q1G33F004 Continuous RWCU System Q1G33F039 Continuous RWCU System Q1G33F034 Continuous RWCU System Q1G33F054 Continuous RWCU System Q1G33F028 Continuous RWCU System Q1G33F053 Continuous RWCU System Q1G33F040 Continuous RWCU System Q1G33F001 Continuous RWCU System Q1G33F250 Continuous RWCU System Q1G33F252 Continuous RWCU System GRAND GULF-UNIT 1 3/4 8-43 Amendment No. 8 s
TABLE 3.8.4.2-1 (Continued)
MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (CON-
.TINUOUS) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (NO)
AFFECTED Q1G41F028 Continuous Spent Fuel Pool Cooling and Cleanup System Q1G41F029 Continuous Spent Fuel Pool Cooling and Cleanup System l
Q1G41F044 Continuous Spent Fuel Pool Cooling and j
. Cleanup System Q1G41F021 No Spent Fuel Pool Cooling and Cleanup System Q1G41F043 No Spent Fuel Pool Cooling and Cleanup System Q1M71F591A Containment /Drywell I&C Q1M71F593A Containment /Drywell I&C Q1M71F5928 Containment /Drywell I&C Q1M71F595 Containment /Drywell I&C Q1M71F5918 Containment /Drywell I&C Q1M71F592A Containment /Drywell I&C Q1M71F594 Containment /Drywell I&C Q1P21F017 Continuous Makeup Water Treatment System Q1P21F018 Continuous Makeup Water Treatment System Q1P41F237 Continuous SSW System Q1P41F018 Continuous SSW System Q1P41F241 Continuous SSW System Q1P41F238 Continuous SSW System QSP41F081A Continuous SSW System QSP41F064A Continuous SSW System Q1P41F068A Continuous SSW System 4
Q1P41F014A Continuous SSW System Q1P41F159A Continuous SSW System Q1P41F160A Continuous SSW System Q1P41F113 Continuous SSW System Q1P41F168A Continuous
-SSW System Q1P41F001A Continuous SSW System Q1P41F016A Continuous SSW System Q1P41F015A Continuous SSW System Q1P41F006A Continuous SSW System Q1P41F005A Continuous SSW System Q1P41F007A Continuous SSW System QSP41F074A Continuous SSW System QSP41F066A Continuous SSW System QSP41F125 Continuous SSW System Q1P41F018B Continuous SSW System Q1P41F160B Continuous SSW System Q1P41F1598 Continuous SSW System Q1P41F1688 Continuous SSW System QSP41F154 Accident Conditions SSW System l
GRAND GULF-UNIT 1 3/4 8-44 Amendment No. 8
l TABLE 3.8.4.2-1 (Continued)
MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (CON-TINUOUS) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (NO)
AFFECTED QSP41F155A Accident Conditions SSW System l
Q1P41F068B Continuous SSW System QSP41F155B Accident Conditions SSW System l
Q1P41F0148 Continuous SSW System QSP41F064B Continuous SSW System l
QSP41F081B Continuous SSW System I
Q1P41F0068 Continuous SSW System Q1P41F0078 Continuous SSW System Q1P41F001B Continuous SSW System Q1P41F0168 Continuous SSW System Q1P41F0058 Continuous SSW System Q1P41F015B Continuous SSW System QSP41F0668 Continuous SSW System QSP41F0748 Continuous SSW System QSP41F189 Continuous SSW System Q1P41F011 Continuous SSW System Q1P41F119A No SSW System Q1P41F1198 No SSW System Q1P41F121A No SSW System Q1P41F121B No SSW System Q1P41F122A No SSW System Q1P41F1228 No SSW System Q3Z51F007 Continuous Control Room HVAC QSZ51F008 Continuous Control Room HVAC QSZ51F014 Continuous Control Room HVAC QSZ51F016 Continuous Control Room HVAC Q1P42F067 Continuous CCW System Q1P42F116 Continuous CCW System Q1P42F028A Continuous CCW System Q1P42F032A Continuous CCW System Q1P42F201A Continuous CCW System Q1P42F204 Continuous CCW System Q1P42F205 Continuous CCW System Q1P42F7 b Continuous CCW System Q1P42F>(uT Continuous CCW System Q1P42F2p3 Continuous CCW System Q1P42F117 Continuous CCW System Q1P42F114 Continuous CCW System Q1P42F068 Continuous CCW System Q1P42F200B Continuous CCW System Q1P42F028B Centinuous CCW System Q1P42F201B CoaM nuous CCW System Q1P42F032B Continuous CCW System Q1P42F066 Continuous CCW System
- Manual bypass of thermal overload protection of manually controlled valve.
GRAND GULF-UNIT 1 3/4 8-45 Amendment No. 8
TABLE 3.8.4.2-1 (Continued)
MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION BYPASS DEVICE (CON-TINUOUS) (ACCIDENT SYSTEM (S)
VALVE NUMBER CONDITIONS) (MO)
AFFECTED Q1P44F053 Continuous Plant SW System Q1P44F069 Continuous Plant SW System Q1P44F076 Continuous Plant SW System Q1P44F070 Continuous Plant SW System Q1P44F074 Continuous Plant SW System Q1P44F077 Continuous Plant SW System Q1P44F042 Continuous Plant SW System Q1P44F054 Continuous Plant SW System Q1P44F067 Continuous Plant SW System Q1P45F096 Continuous Floor & Eqmt. Drain System Q1P45F097 Continuous Floor & Eqmt. Drain System Q1PS2F195 Continuous Service Air System Q1P53F003 Continuous Instrument Air System Q1P53F007 Continuous Instrument Air System Q1T48F005 Continuous SGTS Q1T48F006 Continuous SGTS Q1T48F024 Continuous SGTS Q1T48F026 Continuous SGTS Q1T48F023 Continuous SGTS Q1T48F025 Continuous SGTS Q1P45F273 Continuous Floor & Eqmt. Drain System Q1P45F274 Continuous Floor & Eqmt. Drain System GRAND GULF-UNIT 1 3/4 8-45a Amendment No. 8 l
3/4.11 RADI0 ACTIVE EFFLUENTS 3/4.11.1 LIQUID EFFLUENTS CONCENTRATION LIMITING CONDITION FOR OPERATION 3.11.1.1 The concentration of radioactive material released from the site to unrestricted areas (see Figure 5.1.3-1) shall be limited to the concentrations specified in 10 CFR Part 20, Appendix B, Table II, Column 2 for radionuclides other than dissolved or entrained noble gases.
For dissolved or entrained noble gases, the concentration shall be limited to 2 x 10 4 microcuries/mi total activity.
AFFLICABILITY:
At all times.
ACTION:
With the concentration of radioactive material released from the site exceeding the above limits, immediately restore the concentration to within the above limits.
SURVEILLANCE REQUIREMENTS 4.11.1.1.1 The radioactivity content of each batch of radioactive liquid waste shall be determined prior to release by sampling and analysis in accord-ance with Table 4.11.1.1.1-1.
The results of pre-release analyses shall be used with the calculational methods in the ODCM to assure that the concentration at the point of release is maintained within the limits of Specification 3.11.1.1.
4.11.1.1.2 Post-release analyses of samples composited from batch releases shall be performed in accordance with Table 4.11.1.1.1-1.
The results of the previous post-release analyses shall be used with the calculational methods in the ODCM to assure that the concentrations at the point of release were maintained within the limits of Specification 3.11.1.1.
GRAND GULF-UNIT 1 3/4 11-1 Amendment No. 8
RADI0 ACTIVE EFFLUENTS DOSE LIMITING CONDITION FOR OPERATION 3.11.1.2 The dose or dose commitment to an individual from radioactive materials in liquid effluents released, from each reactor unit, from the site (see l
Figure 5.1.3-1) shall be limited:
I a.
During any calendar quarter to less than or equal to 1.5 mrem to the total body and to less than or equal to 5 mrem to any organ, and b.
During any calendar year to less than or equal to 3 mrem to the total body and to less than or equal to 10 mrcm to any organ.
APPLICABILITY: At all times.
ACTION:
a.
With the calculated dose from the release of radioactive materials in liquid effluents exceeding any of the above limits, in lieu of any other report required by Specification 6.9.1, prepare and submit to the Commission within 30 days, pursuant to Specifica-tion 6.9.2, a Special Report which identifies the cause(s) for exceeding the limit (s) and defines the corrective actions to be taken to ensure that future releases will be in compliance with Specification 3.11.1.2.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.11.1.2 Dose Calculations.
Cumulative dose contributions from liquid effluents shall be determined in accordance with the ODCM at least once per 31 days.
GRAND GULF-UNIT 1 3/4 11-5 Amendment No. 8
i RADIOACTIVE ~ EFFLUENTS DOSE - NOBLE GASES LIMITING CONDITION FOR OPERATION 3.11.2.2 The air dose due to noble gases released in gaseous effluants, from each reactor unit, from the site (see Figure 5.1.3-1) shall be limited to the l
following:
a.
During any calendar quarter:
Less than or equal to 5 mrad for gamma radiation and less than or equal to 10 mrad for beta radiation, and b.
During any calendar year:
Less than or equal to 10 mrad for gamma radiation and less than or equal to 20 mrad for beta radiation.
APPLICABILITY:
At all times.
ACTION:
a.
With the calculated air dose from the radioactive noble gases in gaseous effluents exceeding any of the above limits, in lieu of any other report required by Specification 6.9.1, prepare and submit to the Commission within 30 days, pursuant to Specification 6.9.2, a Special Report which identifies the cause(s) for exceeding the limit (s) and defines the corrective actions to be taken to ensure that future releases will be in compliance with Specification 3.11.2.2.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.11.2.2 Dose Calculations.
Cumulative dose contributions from gaseous effluents for the current calendar quarter and current calendar year shall be determined in accordance with the ODCM at least once per 31 days.
GRAND GULF-UNIT 1 3/4 11-12 Amendment No. 8
)
RADIOACTIVE EFFLUENTS DOSE - N0BLE GASES LIMITING CONDITION FOR OPERATION 3.11.2.2 The air dose due to noble gases released in gaseous effluents, from each reactor unit, from the site (see Figure 5.1.3-1) shall be limited to the l
following:
a.
During any calendar quarter:
Less than or equal to 5 mrad for gamma radiation and less than or equal to 10 mrad for beta radiation, and b.
During any calendar year:
Less than or equal to 10 mrad for gamma radiation and less than or equal to 20 mrad for beta radiation.
APl._ICABILITY: At all times.
ACTION:
a.
With the calculated air dose from the radioactive noble gases in gaseous effluents exceeding any of the above limits, in lieu of any other report required by Specification 6.9.1, prepare and submit to the Commission within 30 days, pursuant to Specification 6.9.2, a Special Report which identifies the cause(s) for exceeding the limit (s) and defines the corrective actions to be taken to ensure that future releases will be in compliance with Specification 3.11.2.2.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.11.2.2 Dose Calculations.
Cumulative dose contributions from gaseous effluents for the current calendar quarter and current calendar year shall be determined in accordance with the ODCM at least once per 31 days.
1 GRAND GULF-UNIT 1 3/4 11-12 Amendment No. 8
RADI0 ACTIVE EFFLUENTS DOSE - RADI0 IODINES, RADI0 ACTIVE MATERIALS IN PARTICULATE FORM, AND TRITIUM LIMITING CONDITION FOR OPERATION 3.11.2.3 The dose to an individual from tritium, radiciodines and radioactive materials in particulate form with half-lives greater than 8 days in gaseous effluents released, from each reactor unit, from the site (see Figure 5.1.3-1) shall be limited to the following:
a.
During any calendar quarter:
Less than or equal to 7.5 mrem to any organ, and b.
During any calendar year:
Less than or equal to 15 mrem to any organ.
APPLICABILITY:
At all times.
ACTION:
a.
With the calculated dose from the release of tritium, radioiodines, or radioactive materials in paticulate form, with half-lives greater than 8 days, in gaseous effluents exceeding any of the above limits, in lieu of any other report required by Specification 6.9.1, prepare and submit to the Commission within 30 days, pursuant to Specifica-tion 6.9.2, a Special Report which identifies the cause(s) for exceeding the limit and defines the corrective actions to be taken to ensure that future releases will be in compliance with Specification 3.11.2.3.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.11.2.3 Dose Calculations.
Cumulative dose contributions from tritium, radioiodines, and radioactive materials in particulate form wth half-lives greater than 8 days for the current calendar quarter and current calendar year shall be determined in accordance with the ODCM at least once per 31 days.
GRAND GULF-UNIT 1 3/4 11-13 Amendment No. 8 j
ADMINISTRATIVE CONTROLS AUDITS 6.5.2.8 Audits of unit activities shall be performed under the cognizance of the SRC.
These audits shall encompass:
a.
The conformance of unit operation to provisions contained within the Appendix A Technical Specifications and applicable license conditions at least once per 12 months.
b.
The performance, training and qualifications of the entire unit staff at least once per 12 months.
The results of actions taken to correct deficiencies occurring in c.
unit equipment, structures, systems or method of operation that affect nuclear safety at least once per 6 months.
d.
The performance of activities required by the Operational Quality Assurance Program to meet the criteria of Appendix "B", 10 CFR 50, at least once per 24 months.
The Emergency Plan and implementing procedures at least once per e.
12 months.
f.
The Security Plan and implementing procedures at least once per 12 months.
g.
Any other area of unit operation considered appropriate by the SRC or the Senior Vice President - Nuclear.
h.
The Fire Protection Program and implementing procedures at least once per 24 months.
i.
An independent fire protection and loss prevention inspection and audit shall be performed at least once per 12 months utilizing either qualified offsite licensee personnel or an outside fire protection firm.
j.
An inspection and audit of the fire protection and loss prevention program shall be performed by an outside qualified fire consultant at intervals no greater than 36 months.
k.
The radiological environmental monitoring program and the results thereof at least once per 12 months.
1.
The OFFSITE DOSE CALCULATION MANUAL and implementing procedures at least once per 24 months.
m.
The PROCESS CONTROL PROGRAM and implementing procedures for solidification of radioactive wastes at least once per 24 months.
The performance of activities required by the Quality Assurance n.
Program to meet the criteria of Regulatory Guide 4.15, February 1979, at least once per 12 months.
GRAND GULF-UNIT 1 6-11 Amendment No. 8
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