ML20027C130
| ML20027C130 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  (NPF-13-A-003, NPF-13-A-3) |
| Issue date: | 09/20/1982 |
| From: | Eisenhut D Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20027C131 | List: |
| References | |
| NUDOCS 8210130029 | |
| Download: ML20027C130 (16) | |
Text
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.[ I MISSISSIPPI POWER A!10 LIGHT C0'4PANY fIIDDLE SOUTH ENERGY, IteC.
SOUTH ttISSISSIPPI ELECTRIC POWER ASSOCIATION DOCKET H0. 50-416 GRAliD GULF NUCLEAR STATION, UNIT 1 A!!ENDMENT TO FACILITY OPERATIliG LICENSE License No. t4PF-13 Amendment No. 3 1.
The Nuclear Regulatory Comission (the Comission or the NRC) having found that:
A.
The two applications for the anendments filed by the flississippi Power and Light Company dated September 13, 1982 comply with the standards and requirements of the Atonic Energy Act of 1954, as acended (the Act), and the Comission's regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, tf;e provisions of the Act, and the regulations of the Comission; C.
There is reasonable assurance:
(1) that the activities authorized by this amendnent can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Cocnission's regulations; D.
The issuance of this anendaent 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 anendaent 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 as follows:
A.
Page changes to the Technical Specifications as indicated in the attachment to this license ancadment and paragraph 2.C.(2) to read as follows:
(2) The Technical Specifications contained in Appendix A, as revised through Amendment flo. 3, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license.
. The licensee shall operate the faci'ity in accordance with the Technical Specifications and the Environnental Protection Plan.
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B.
Change paragraph 2.C.(42) (t) and (g) to read as follows:
(f) Provided that the outboard itSIVs and the main stearn shutoff valves are closed, the provisions of the following specifi-cations nay be susperded:
3.3.1, Tabic 3.3.1-1, Itec:: 7; 3.3.2, Table 3.3.2-1, Iten 2b; 3.3.7.1, Table 3.3.7.1-1, Itens 3,4 and 5; 3.3.7.5, Table 3.3.7.5-1, J tem 17; 3.4.7 and 3.6.1.4.
(9) The provisions of specification 3.3.7.10, 3.4.3.1.a and 3.7.3 may be suspended.
3.
This a.aendraent is effective at of the date of issuance.
FOR THE NUCLEAR REGULATORY C0!#11SSION f,
9 Darrell G. Eisenhut, Director Division of Licensing Office of duclear Reactor Regulation Date of issuance: Septenber 20, 1982 l
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2-B.
Ct)ange paragraph 2.C.(42) (f) and (g) to read as,follows:
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(f)P.rovided that the outboard t451Vs ando.he main steam shutoff vh ves are closed, the provisions-6f the following specifi-Cations may be suspended:
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3.3.1, Table 3.3.1-1, Iten 7; 3.3.2, Table 3.3.2-1, s
Itect 2b; 3.3.hl, Table' 3.3.7.1-1, Itens 3,4 and 5; 3.3.7.5, Table 3'.'3,7'.5-1, Iten 17; 3.4.7 and 3.6.1.4.
The provisions'of s\\
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fg) pecification 3.3.7.10, 3.4.3.1.a and 3.7.3 nay be suspended.
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3.
This amendment is effe[tive as of the date ofdssuance.
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N FOR THE HUCLEAR REGULATORY C0ttilSSION N
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Darrell G. Eisenhut, Director
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Division of Licensing Office of Huclear Reactor degulatioh Date of issuance: September 17, 1962 I
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.W SAFETY EVALUATIOt4 AME!19?tEf1T ti0. 3 TO flPF-13 GRAtiD GULF I40 CLEAR STATIO!!, UtilT 1 DOCKET 140. 50-416 Introduction The licensee proposed a chance to the operating license and changes to the Technical Specifications for Grand Gulf Unit I which are as follows:
a)
Incorporation of additional one time Technical Specification exceptions for Phase I op3 rations OtP&L letter dated September 13,1982).
b) Changes to the following Technical Specifications (flP&L letter dated September 13,1952):
(1) Table 3.6.4-1, Valve E12-F021B Stroke Tine.
(2) 4.5.1.C.2.a. " Keep Filled" Pressure Alarm Surveillance.
(3) Table 3.3.8-2, Containment Spray Initiation Time.
(4) Table 3.8.4.1-1, flolded Case Circuit Breaker Response Tine.
Evaluation a) One Time Technical Specification Exceptions In the license, the staff granted certain sne time exceptions fron the Technical Specifications prior to execeding 1.0 percent of rated thermal power for the first time. Since then, the licensee has identified other Tecnnical Specifications for which they need an exception for Phase I operation. The bases for tha requested exceptions are consistent with the rationale and justification used in the fornulation of the original license condition. The requested exceptions are related to system', which will be isolated or non-functional during Phase 1 operation or to systens which monitor fission product inventory. At power levels less than 1.0 percent power, there will be a sufficiently low fission product inventory so that these associated systems will not be require <l.
The staff has revieaed the nature of the requested exceptions and the bases for the requests and finds that a one time exception for Phase 1 operatirn is acceptable.
Therefore, the additional exceptions from the Technical Specifications are granted.
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-z-b) Technical Specification Changes (1) Table 3.b.4.1, Yalve E12-F0213 Stroke Tine A design change to the containment and drywell isolation valve was made during plant construction to allow for throttling flow in the RHR "C" test line to the suppression pool. The design bases, as detailed in the NSSS supplier's design specification, is that the RHR system is-not required to recover from secondary nodes of operation, such as testing, within the specified LPCI injection tiae, because the interval of tine the RiiR systesa re.nains in these secondary modes is so short that the effect on overall reliability is insignificant. Therefore, the licensee has requested that the valve stroke tine for valve E12-FC213 be chanjed fron 67 seconds to 101 seconds.
We have reviewed the licensee's request and the RHR systeu piping and instru..entation diagrams. Valve E12-F0218 is the isolation valve in the RHR test return line to the suppression pool, and is nor:ully closed.
Its safety function is to close upon receipt of an ECCS initiation signal, (should it be open during a system test) to allow realignnent of the RiR systed for LPCI injection. There is only a very short time period during which the safety function of this valve could be required (i.e. a LOCA occurs during the RHR systen test). Also, only one loop is tested at a tine and hence 2 other LPCI loops as well as the LPCS and HPCS systems would be available for injection. Based upon our review, we find the proposed change to the Technical Specification acceptable.
(2) Table 4.5.1.C.2.a. " Keep Filled" Pressure Alarn S1rveillance The licensee has requested a change in the low pressu e alarn setpoints for the " Keep Filled" systen in the ECCd discharge lines. The pressure alarns are indicative of voids or "not full" discharge lines. Full discharge lines are iuportant in preventing water hamer events. The change in setpoints has been requested to reflect plant specific conditions at Grand Gulf.
ble have reviewed the revised alara setpoints proposed by the licensee, and the elevation differences between the neasurement point and the system high point for the HPLS, LPCS, and LPCI systcas. He conclude that the alara setponts are above the static head difference between the systea high points and the neasurenent point. Based on our review, we find the proposed change to the Technical Specification acceptable.
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,o C (3) Table 3.3.8-2, Contairnent Spray Initiation Tine The current Technical Specification for the containnent spray tiners require that the setpoint and allowable value be less than or equal to ten ainutes. Ilowever, in Section 6.2.1.1.5.5 of the Final Safety Analysis Report for Grand Gulf, the containnent sprays are assumed to be initiated no sooner than ten ainutes following a LOCA and no later than thirteen minutes. The licensee has requested that the containment spray initiation time be changed consistent with the Final Safety Analysis Report and our previous safety review, We have reviewed the licensee's justification for this change and find the proposed Technical Specification change acceptable.
(4) Table 3.8.4.1-1, Holded Case Circuit Breaker Response Tine The licensee has requested an increase in the response time to 0.1 seconds for Type !W1 circuit breakers. This change revises the fuse t/ pes used in the Grand Gulf design. For a worst-case condition, a limiting factor is the heating of a #1/0 penetration pigtail in 0.147 seconds to 250 C.
Type lei molded case circuit breakers will respond within the worst-case condition tine limit. Based on uljnEG-0586,
" Equipment Qualification of Safety-Related Electrical Equipment", the thernal capability of this unit with this response time i5 within the allowable limits. Therefore, we find the proposed change to the Technical Specification acceptable.
Environmental Consideration We have determined that this anendment does not authorize a change in effluent types or total amount nor an increase in power level and will not result in any significant environmental impact. Itaving made this determination, we have further concluded that this amendnent involves action which is insignificant from the standpoint of environnental impact, and, pursuant to 10 CFR Section Sl.5(d)(4), that an environmental inpact statement or negative declaration and environnental inpact appraisal need not be prepared in connection with the issuance of this statenent.
Conclusion, We have concluded, based on the considerations discussed above, that:
(1) because the anendaent does not involve a significant increase in the probability or consequences of accidents previously considered and does not involve a significant decrease in a safety aargin, the amendment does not involve s significant hazards consideration, (2) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the prooosed manner, and (3) such activities will be conducted in coupliance with the Conmission's regulations and the issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public.
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jj PLANT SYSTEMS ACTUATION INSTRUMENTATION SETPOINTS l.
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ALLOWABLE l
TRIP FUNCTION TRIP SETPOINT VALUE j
1 C
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1.
CONTAINMENT SPRAY SYSTEM l
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a.
Drywell Pressure-High 1 1.89 psig 1 1.94 psig b.
Containment Pressure-High 5 9 psig 5 9.2 psig i
c.
Reactor Vessel Water Level-Low Low Low, Level 1
> - 150.3 inches
> - 152.5 inches d.
Timers 1
- 1) System A 10.3 +.1 minutes 10 + 1.7, -0 minutes
- 2) System B 11.2 +.2 minutes 11.5 +
.2, -1.5 minutes 2.
FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM l
a.
Reactor Vessel Water Level-High, level 8 1 53.5 inches *
$ 55.7 inches
.T, uo "See Bases Figure B 3/4 3-1.
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t EMERGENCY CORE COOLING SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)
ACTION:
(Continued) e.
For ECCS divisions 1 and 2, provided that ECCS division 3 is OPERABLE and divisions 1 and 2 are otherwise OPERABLE:
1.
With one of the above required ADS valves inoperable, restore the inoperable ADS valve to OPERABLE status within 14 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 reduce reactor steam dome pressure to 5 135 psig within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
2.
With two or more of the above required ADS valves inoperable, 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 reduce reactor steam dome pressure to 1 135 psig within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
f.
With an ECCS discharge line " keep filled" pressure alarm instrumentation channel inoperable, perform Surveillance Requirement 4.5.1.a.1 at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
g.
With an ECCS header delta P instrumentation channel inoperable, restore the inoperable channel to OPERABLE status with 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or de'termine ECCS header delta P locally at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />; otherwise declare the associated ECCS inoperable.
h.
In the event an ECCS system is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and sub-mitted to the Commission pursuant to Specification 6.9.2 within 90 days describing the circumstances of the actuation and the total accumulated actuation cycles to date.
The current value of the useage factor for each affected safety injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.
- Whenever two or more RHR subsystems are inoperable, if unable to attain COLD SHUTDOWN as required by this ACTION, maintain reactor coolant temperature as low as practical by use of alternate heat removal methods.
GRAND GULF-UNIT 1 3/4 5-3 em e r.
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EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 2)
Low pressure setpoint of the:
(a) LPCI A and B subsystem loop to be 1 38 psig.
(b) LPCI C subsystem loop and LPCS system to be 1 22 psig.
(c) HPCS system to be 1 18 psig, b)
Header delta P instrumentation and verifying the setpoint of the HPCS system and LPCS system and LPCI subsystems to be 1.2 1 0.1 psid change from the normal indicated AP.
3.
Verifying that the suction for the HPCS system is automatically transferred from the condensate storage tank to the suppression pool on a condensate storage tank low water level signal and on a suppression pool high water level signal, d.
For the ADS 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, but excluding actual valve actuation.
2.
Manually opening each ADS valve when the reactor steam dome pressure is greater than or equal to 100 psig* and observing that either:
a)
The control valve or bypass valve position responds accordingly, or b)
There is a corresponding change in the measured steam flow.
l A
The provisions of Specification 4.0.4 are not applicable provided the surveillance is performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure is adequate to perform the test.
GRAND GULF-UNIT 1 3/4 5-5 Amendment No. 3
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TABLE 3.6.4-1 CONTAINMENT AND DRYWELL ISOLATION VALVES MAXIMUM SYSTEM AND PENETRATION ISOLATION TIME VALVE NUMBER NUMBER VALVE GROUP (a)
(Seconds) 1.
Automatic Isolation Valves a.
Conts'nment Main Stear 'snes B21-F028A 5(0) 1 5
Main Steam..ines B21-F022A 5(I) 1 5
Main Steam Lines B21-F067A-A 5(0) 1 6
Main Steam Lines B21-F028B 6(0) 1 5
Main Steam Lines B21-F022B 6(I) 1 5
Main Steam Lines 821-F067B-A 6(0) 1 6
Main Steam Lines 821-F028C 7(0) 1 5
Main Steam Lines B21-F022C 7(I) 1 5
Main Steam Lines 821-F067C-A 7(0) 1 6
Main Steam Lines B21-F028D 8(0) 1 5
Main Steam Lines 821-F0220 8(I) 1 5
Main Steam Lines B21-F067D-A 8(0) 1 6
RHR Reactor E12-F008-A 14(0)(c) 3 40 Shutdown Cooling Suction RHR Reactor E12-F009-B 14(I)(C) 3 40 Shutdown Cooling Suction Steam Supply to E51-F063-B 17(I) 4 20 RHR and RCIC Turbine Steam Supply to E51-F064-A 17(0) 4 20 RHR and RCIC Turbine Steam Supply to E51-F076-B 17(I) 4 20 RHR and RCIC Turbine RCIC and RHR to E12-F023-B 18(0)(c) 3 90 Head Spray l
Main Steam Line B21-F019-A 19(0) 1 15 Drains Main Steam Line B21-F016-B 19(I) 1 15 Drains i
RHR Heat Exchanger E12-F042A-A 20(I)(c) 5
- 22 "A" to LPCI (a) See Specification 3.3.2, Table 3.3.2-1, for isolation signal (s) that operates each valve group.
(b) Hydrostatically tested to ASME Sec* ion XI criteria.
11.5 p.1g.
Hydrostatically tested with water at P,s,ystem to 1.10 P,, 12.65 psig.
(c)
Hydrostatically tested by pressurizing (d)
(e) Hydrostatically tested during system functional tests.
(f) Hydrostatically sealed by feedwater 1Eaksac control system.
Type C test not required.
GRAND GULF-UNIT 1 3/4 6-29
L TABLE 3.8.4.1-1 (Continued)
PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES 480 VAC Molded Case Circuit Breakers (Continued)
-Type NZM (Continued)
TRIP
RESPONSE
BREAKER SETPOINT TIME SYSTEM / COMPONENT NUMBER (Amperes)
(Seconds)
AFFECTED l
52-1642-10 320 0.018 DRYWELL COOLER FAN COIL UNIT (N1M518006B-8) 52-1642-14 12.5 0.018 MOV - DRWELL COOLER INLET (N1P44F056-B) 52-1642-15 12.5 0.018 MOV - DRWELL COOLER INLET (N1P44F058-B) 52-1642-16 12.5 0.018 MOV - DRWELL COOLER INLET (N1P44F060-B) 52-1642-17 12.5 0.018 MOV - DRWELL COOLER INLET (N1P44F062-B) 52-1642-18 12.5 0.018 MOV - DRWELL COOLER INLET (N1P44F064-B) 52-1642-19 12.5 0.018 MOV - DRWELL COOLER INLET (N1P44F066-B) i 52-1642-21 24 0.018 DRWL PURGE COMP AUX OIL PUMP (Q1E61C0018-B)
GRAND GULF-UNIT 1 3/4 8-37
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