ML20210Q870
| ML20210Q870 | |
| Person / Time | |
|---|---|
| Site: | River Bend  (NPF-47-A-095, NPF-47-A-95) |
| Issue date: | 08/26/1997 |
| From: | Wigginton D NRC (Affiliation Not Assigned) |
| To: | |
| Shared Package | |
| ML20210Q876 | List: |
| References | |
| NUDOCS 9709020190 | |
| Download: ML20210Q870 (17) | |
Text
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UNITED STATES y
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NUCLEAR REGULATORY COMMISSION 2-WASHINGTON, D C. 30eeHo01
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I GULF STATES UTILITIES COMPANY **
CAJUN ELECTRIC POWER COOPERATIVE AND ENTE".GY OPERATIONS. INC.
4 DOCKET NO. 50-458 RIVER BEND STATION. UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.95 License No. NPF-47 1.
The Nuclear Regulatory Commission (the Commission) has found that:
A.
The application for amendment by Gulf States Utilities * (the licensee) dated October 26, 1995 and sup)1emented by letters dated April 7 and July 30,1997, complies with tie standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission; C.
There is reasonable assurance:
(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.
The issuance of this license amendment will not be inimical to the common defense and security or to the health and safety of the public; and E01 is authorized to act as agent for Gulf States Utilities Company, which has been authorized to act as agent for Cajun Electric Power Cooperative, and has exclusive responsibility and control over the physical construction, operation and maintenance of the facility.
- Gulf States Utilities Company, which owns a 70 percent undivided interest in River Bend, has merged with a wholly owned subsidiary of Entergy Corporation. Gulf States Utilities Company was the surviving company in the merger.
9709020190 970326 PDR ADOCK 050)O458 P
- E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have I
been satisfied.
2.
Accordingly, the license is amended by changes to the _ Technical Specifications as indicated in the attachment to this license amendment; l
and Paragraph 2.C.(2) of Facility Operating License No. NPF-47 is hereby amended to read as follows:
(2) Technical Soecifications and Environgg,ntal Protection Plan The Technical Specifications contained in Appendix A, as revised I
through Amendment No. 95 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license.
E01 shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
The license amendment is effective as of its cate of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION David L.
inton, Senior Project Manager Pr.'iect Directorate IV-1 Die sion of Reactor Projects III/IV Office of Nuclear Reactor Regulation
Attachment:
Changes to the Technical Specifications Date of Issuance: August 26, 1997 9
ATTACHMENT T0 LICENSE AMENDMENT NO.95 FACILITY OPERATING LICENSE NO. NPF-47 QQCKET NO. 50-458 Replace the following pages of the Appendix A Technical Specifications with the attached pages. The revised pages are identified by Amendment number and contain marginal lines indicating the areas of change.
i REMQYE INSERT 3.2-4 3.2-4 3.3-22 3.3-22 3.3-69 3.3-69 3.3-71 3.3-71 3.3-74 3.3-74 3.4-31 3.4-31 3.6-47 3.6-47 3.6-50 3.6-50 3.6-55 3.6-55 3.8-13 3.8-13 3.8-17 3.8-17 3.8-39 3.8-39 5.0-16 5.0-16 5.0-21 5.0-21
APRM Gain and Setpoints
-3.204 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Average' Power Range Monitor (APRM) Gain and Setpoints i
a.
T shall be 11.0; or b.
Each required APRM setpoint specified in the COLR shall be made applicable; or c.
Each recuired APRM gain shall be adjusted such that the adjustec APRM readings result in a calculated T 11.0 l
when the APRM reading is substituted for Fraction of Rated Thermal Power (FRTP).
APPLICABILITY:
THERMAL POWER k 25% RTP.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
Requirements of the A.1 Satisfy the 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> LCO not met.
requirements of the LCO.
I B.
Required Action and B.1 Reduce lilERMAL POWER 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion to < 25% RTP, Time not met.
RIVER BEND 3.2-4 Amendment No. 81,95
PAM Instrumentation 3.3.3.1 febte 3.3.3.1 1 (page 1 of 1)
Poet Acclient Itanttoring Instrumentetten CONDifl0MS kEFERENCED FROM REGUIRED REeulRED f W CTION CNANNELS ACTiou D.1
- 1. aeector steen Does Pressure 2
E 2.
Reester Weseet Water Levet 4lde targe 2
E 3.
Geester Weseet Water LovetMust 2ene 2
E 4.
egpreselen Poet Water towet 2
E 5.
sgproselen Poet sector Water Temperature 2(*)
E 6.
Drywell Preneure 2
E 7.. Primary Centelrusent Preneurv 2
E 8.
Drywell Aree Pedletten 2
F 9 Primary Centelteent Area tedletten 2
F
- 10. Drywelt N, Anotyser 2
E
- 11. Centalrusent M. Anotyser 2
E l
- 12. Penetretten Flow Path, Auteestic PCiv Peeltlen 2 per tgtig flow E
(e) Naniterleg each of two sectors.
(b) met regelred for toeletlen welwoo whose essecleted penetretten flew path to feetated.
(c) enty one peeltlen indloetten ehemet le regaired for penetretten flew paths with enty one centret reen indication ehemet.
RIVER BEND 3.3-22 Amendment No. 8t,95
CRFA System Instrumentation 3.3.7.1 ACTIONS (continued) 1 CONDITION REQUIRED ACTION COMPLETION TIME C.
As required by C.1 Declare associated I hour from Required Action A.)
CRFA subsystem discovery of and referenced in inoperable.
loss of CRFA Table 3.3.7.1-1.
initiation capability in-both trip systems AND C.2 Place channel in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> trip.
D.
As required by D.1 Declare associated I hour from Required Action A.1 CRFA subsystem discovery of and referenced in inoperable.
loss of CRFA Table 3.3.7.1-1, initiation.
capability in both trip systems AND D.2 Place channel in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> trip. -
E.
Required Action and E.1 Place the associated I hour associated Completion CRFA subsystem in l
Time of Condition B, emergency mode.
C, or D not unt.
QB E.2 Declare associated CRFA subsystem I hour c
2 RIVER BEND 3.3-69 Amendment No. 8+,95 n-4.
1 CRFA System Instrumentation 3.3.7.1 i
(
Tabte 3.4 7.1 1 (pose 1 of 1)
Centrol Room Fresh.'.Ir system Instrsmontation APPLICABLE CONDIT10NS MODES OR REQUIRED REFERENCED OTNER CNANNELS FROM SPECIFIED PER TRIP RfeUIRED SURVEILLANCE ALLO W LE PLalCTION COWITIONS SYSTEM ACTION A.1 REQUIRENEhi$
VALUE 1.
aeector veneet Water 1,2,3 2
5 st 3.3.7.1.1 t -47 inches Level-Low Low,tevel 2 st 3.3.7.1.1 at 3.3.7.1.3 I
st 3.3.7.1.5 2.
Drywell Pressure-RIsh 1,2,3 2
C st 3.3.7.1.1 s 1.88 paid SR 3.3.7.1.2 st 3.3.7.1.3 at 3.3.7.1.4 l
st 3.3.7.1.5 3.
Control Room Local 1.2,3 1
D st 3.3.7.1.1 s 0.97 a 10*'
Intake ventitation (a),(b) at 3.3.7.1.2 pct /cc i
Radletion Monitore at 3.3.7.1.4 l
st 3.3.7.1.5
's) During operations with a potentlet for draining the reactor vesset.
(b, During CORE ALTERATIONS and dJring movenant of irradiated fuel mesemblies in the primary or secondary contelnment.
I RIVER BEND 3.3-71 Amendment No. M,95 e-i.
LOP Instrumentation 3.3.8.1 Table 3.3.8.1 1 (pope 1 of 1)
Loss of Power Instnmentation aroultED CHANNELS PER sLRVEILLANCE ALL0d48LE FUNC180N DIVillou StallRDIENTS VALUE 1.
Olvistens 1 and 2-4.16 kV Smereeney sus undervoltese e.
Lose of Voltese-4.16 kV 3
sa 3.3.8.1.1 t 2850 V and s 3090 V beste at 3.3.8.1.2 at 3.3.8.1.3 at 3.3.8.1.4 b.
Lees of Voltepe-flee 3
sa 3.3.8.1.2 t 2.67 eaceran and Deley sa 3.3.8.1.3 s 3.33 seconds et 3.3.8.1.4 c.
Degraded Voltese-4.16 kV 3
at 3.3.8.1.1 t 3605 V and s 3875 V bests sa 3.3.8.1.2 sa 3.3.8.1.3 sa 3.3.8.1.4 d.
Deereded voltese - flee 3
sa 3.3.8.1.2 t 53.4 seconds and Detsy, no LOCA sa 3.3.8.1.3 s 66.6 seconds sa 3.3.8.1.4 e.
Deereded voltepe-Time 3
sa 3.3.8.1.2 1 2.67 seconds and l
Detey, LOCA st 3.3.8.1.3 s 3.33 seconds SR 3.3.8.1.4 2.
Olvision 3-4.16 kV Esereeney tus undervottepe e.
Loss of Voltese-4.16 kV 2
SR 3.3.8.1.1 t 2831 V and s 3259 Y bests at 3.3.8.1.3 sa 3.3.8.1.4 b.
Loss of Voltese-Time 2
sa 3.3.8.1.3 t 2.67 occonds and Delay SR 3.3.8.1.4 s 3.33 seconds c.
Degraded Voltese-4.16 kV 2
at 3.3.8.1.1 t 3702 V and s 3852 Y bests sa 3.3.8.1.2 34 3.3.8.1.3 at 3.3.8.1.4 d.
Deereded Voltese-Time 2
sa 3.3.8.1.2 t 53.4 seconds and
> Detty, he LOCA st 3.3.8.1.3 s 66.6 seconds at 3.3.8.1.4 e.
Deereded Voltese-fles 2
et 3.3.8.1.2 12.67 seconds and OeLay, LOCA at 3.3.8.1.3 s 3.33 seconds at 3.3.8.1.4 t
RIVER BEND 3.3-74 Amendment No. 81,95
RCS P/T L1:::its 3.4.11 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY
(
NOTE-------------------
Only required to be met in sing'le loop
~
operation during increases in HERMAL POWER
... or recirculation loop flow with the Yecirculation loop flow in the operating s
loop s 50% of rated recirculation loop flow l
.'or THERMAL POWER s 30% of RTP.
Verify the difference between the bottom Once within head coclant temperature and the RPV 15 minutes-coolant temperature is s 100*F.
prior to an increase in THERMAL POWER or an increase in loop flow SR 3.4.11.9
NOTE--------------------
Only required to be met in single loop operation during increases in THERMAL POWER or recirculation loop flow with the recirculation loop flow in the operating loop s 50% of rated recirculation loop l
flow, or THERMAL POWER s 30% of RTP, and the idle recirculation loop not isolated from the RPV.
Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop not in operation and the RPV coolant prior to an temperature is s 50*F.
increase in THERMAL-POWER or an increase in loop flow o.
RIVER BEND 3.4-31 Amendment No. 81,95
Secondary Containment @ eratin 3.6.4. --
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.4.1.2 Verify all secondary containment 31 days squipment hatches are closed and sealed l
' # and loop seals filled.
4 e
SR 3.6.4.1.3 Verify each secondary containment access 31 days door is closad, except when the access opening is being used for entry and exit.
SR 3.6.4.1.4 Verify each standby gas treatment (SGT) 18 months on subsystem will draw down the shield a STAGGERED l
building annulus and auxiliary building TEST BASIS l
to 1 0.5 and h 0.25 inch of vacuum l
water gauge in s 18.5 and s 13.5 seconds, respectively.
SR 3.6.4.1.5 Verify each fuel building ventilation 18 months on a subsystem will draw down the fuel STAGGERED TEST building to 1 0.25 inch of vacuum water BASIS gauge in s 12.5 seconds.
SR 3.6.4.1.6 Verify each SGT subsystem can maintain 18 months on a 1 0.5 and 2 0.25 inch of vacuum water STAGGERED TEST gauge in the shield building annulus and BASIS auxi?'.ary building, respectively, for I hour.
SR 3.6.4.1.7 Verify each fuel building ventilation 18 months on a subsystem can maintain 2 0.25 inch of STAGGERED TEST-vacuum water gauge in the fuel building BASIS for I hour.
RIVER BEND 3.6-47 Amendment No. 81,95
_,.m_____
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SCIDs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 Verify the isolation time of each 92 days l
required power operated automatic SCID is l
within limits.
l SR 3.6.4.2.2 Verify each required automatic SCID 18 months actuates to the isolation position on an actual or simulated automatic isolation signal.
I RIVER BEND 3.6-S0 Amendment No. 81,95
-M M
Full Building 3.6.4.5 3.6 CONTAINMENT SYSTEMS 3.6.4.5 Fuel Building LCO 3.6.4.5 The fuel butiding shall be OPERABLE.
APPLICABILITY:
During movement of irradiated fuel assemblies in the fuel building.
ACTIONS
NOTE------------------------------------------
LCO 3.0.3 is not applicabic.
CONDITION REQUIREDt.CTION COMPLETION TIME A.
Fuel building A.1 Suspend movement of Immediately inoperable.
Irradiated fuel assemblies in the fuel building.
SURVEILLANCE REQUIREMENTS-SURVEILLANCE FREQUENCY SR 3.6.4.5.1 Verify fuel building vacuum is 10.25 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inch of vacuum water gauge.
SR 3.6.4.5.2 Verify all fuel building equipment hatch 31 days covers are installed.
SR 3.6.4.5.3 Verify each fuel building access door is 31 days closed, except when the access opening is being used for entry and exit.
RIVER BEND 3.6-55 Amendnent No. Bl. 95 0
AC Sources--Operatin 3.8.
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY f
1 J
SR 3.8.1.16
NOTE-------------------
This Surveillance shall not be performed in MODE 1 2, or 3.
However, credit may be taken for unplanned events that satisfy this SR.
Verify, with a DG operating in test mode 18 months and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:
a.
Returning DG to ready-to-load operation; and 1
b.
Automatically energizing the emergency loads from offsite power.
SR 3.8.1.17
NOTE--------------------
l This Surveillance shall not be performed in MODE 1, 2, or 3.
However, credit may be taken for unplanned events that satisfy this SR.
Verify sequence time is within i 10% of 18 months design for each load sequencer timer.
(continued)
RIVER BEND 3.8-13 Amendment No. 81,95
AC Sources-Shutdown-3c8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources-Shutdown LC0 3.8.2-
.The following AC electrical power sources shall be OPERABLE:
a.
One qualified circuit between the offsite transmission network and the onsite Class IE AC ele 9rical power distribution subsystem (s) required by LC0 3.8.10, l
' Distribution Systems-Shutdown";
b.
One diesel generator (DG) capable of supplying one division of the Divis9on I or II onsite Class IE AC electrical power distribution subsystem (s) required by LC0 3.8.10; and c.
One qualified circuit, other than the circuit in LC0 3.8.2.a. between the offsite transmission and the Division III onsite Class IE electrical power distribution subsystem, or the Division III DG capable of supplying the Division III onsite Class IE AC electrical power distribution subsystem, when the Division III onsite Class IE electrical power distribution subsystem is required by LCO 3.8.10.
l APPLICA8ILITY:
. MODES 4 and 5, During movement of irradiated fuel assemblies in the primary containment or fuel building.
+,,
RIVER BEND
.3.8-17 Amendment No. M,95
Distributien Systems-Operating 3.8.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.
One or more Division I C.1 Restore Division I 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or 11 DC electrical and II DC electrical i
power distribution power distribution 8tiQ subsystems inoperable, subsystems to-OPERABLE status.
16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from 1
discovery of failure to meet LC0 D.
Required Action and D.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, AtlD B, or C not met.
D.2 Be in MODE 4.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E.
One or more E.1 Declare High Pressure immediately l
Division III AC or DC Core Spray System and electrical power Standby Service Water distribution System pump 2C subsystems inoperable.
F.
Two or more divisions F.1 Enter LC0 3.0.3.
Isumediately with' inoperable
. distribution subsystems that result in a -loss of function.
RIVER BEND 3.8-39 Amendment No. St,95 w - o =- p e,-
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Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Technical soecifications (TS) Bases Control Proaram (continued) c.
The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the USAR.
d.
Proposed changes that ~ do not meet the criteria of either S acification 5.5.11.b.1 or Specification 5.5.11.b.2 above ssall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be prcvided to the NRC on a frequency consistent with 10 CFR 50.71(e).
l 5.5.12 DELETED 5.5.13 Primary Containment Leakaae Rate Testina Proaram
. A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54 o Appendix J, Option B, as modified by approved (ex)emptions.and 10 CFR 50, This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, " Performance-Based Containment Leak-Test Program," dated September 1995.
The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 7.6 psig.
The maximum allowable primary containment leakage rate, L, at Pai a
shall be 0.26% of primary containment air weight per day.
The Primary Containment leakage rate acceptance criterion is s 1.0 L.
During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are s 0.60 La for the Type B and Type C tests and s 0.75 La for Type A tests.
The provisions of SR 3.0.2 do not apply to test frequencies specified in the Primary Containment Leakage Rate Testing Program.
The provisions of SR 3.0.3 are-applicable to the Primary Containment
. Leakage Rate Testing Program.
?
b<
RIVER BEND 5.0-16 Amendment No. 8be4,95
High Rad lntion Area 5.7 5.7 HighRadiationArea 1
I 5.7.2 (continued) the inmediate work creas and the maximum allowable stay times for individuals in those areas.
In lieu of the stay time specification of the RWP, direct or remote (such as closed circuit
'TV cameras continuous surveillance may be made by personnel qualified n radiation >rotection procedures to provide positive exposure control over tie activities being perfonned within the area.,
5.7.3 In addition to the requirements of Specification 5.7.1, for individual high radiation areas with radiation levels of h 1000 mrom/hr, accessible to personnel, that are located within large areas such as reactor containment, where no enclosure exists l
for purposes of locking, or that is not continuously guarded, and where no enclosure can be reasonably constructed around the individual area, that individual area shall be barricaded and conspicuously posted, and a flashing light shall be activated as a warning device, l
l l
l l
r RIVER BEND 5.0-21 Amendment No. E,95 A
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