ML17215B014
| ML17215B014 | |
| Person / Time | |
|---|---|
| Site: | Beaver Valley |
| Issue date: | 06/28/1984 |
| From: | DUQUESNE LIGHT CO. |
| To: | |
| Shared Package | |
| ML17215B012 | List: |
| References | |
| NUDOCS 8407180082 | |
| Download: ML17215B014 (14) | |
Text
TABLE 3.3-3 (Continued ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION FUNCTIONAL UNIT 7.
AUXILIARY FEEDWATER TOTAL NO.
CHANNELS OF CHANNELS TO TRIP MINIMUM CHANNELS OPERABLE APPLICABLE MODES ACTION a.
Steam Gen.
Water Level-Low-Low Start Turbine Driven Pump ii.
Start Motor Driven Pumps 3/stm.
gen.
2/stm.
gen.
2/stm.
gen.
1, 2, 3
any stm.
gen.
3/stm.
gen.
2/stm.
gen.
2/stm.
gen.
1, 2, 3
any 2 stm.
gen.
14 14 b.
Undervoltage-RCP (Start Turbine Driven Pump)
(3)-1/bus 14 c.
S.I. (Start Motor-Driven Pumps)
See 1 above (all S.I. initiating functions and requirements) d.
Turbine Driven Pump Discharge Pressure Low (2)-1/Train With Steam Yalve Open-(Start Motor-Driven Pump) e.
Emergency Bus Undervoltage (Start Motor Driven 1/bus Pumps) 1, 2, 3
1.2 3
18 18 f.
Trip of Hain Feedwater Pumps - (Start Motor Driven Pumps) 1/pump 1 2.3 18 P
05000ggy PDR gDOCK 840gg8 8i071 80082 =--
- pan,
TABLE 3.4-4 Continued ENGINEERED SAFETY FEATURE ACTUATIOH SYSTEtl INSTRUhlENTATIOH TRIP SETPOINTS FUNCTIONAL UNIT 4.
STEAN LINE ISOLATION a.
Manual b.
Automatic Actuation Logic c.
Containment Pressure--
Intermediate-High-High d.
Steamline Pressure-Low e.
High Negative Steam Pressure Rate 5.
TURBINE TRIP AHD FEEDWATER ISOLATIOH Cl a.
Steam Generator Water Level lligh-High 6.
LOSS OF POWER TRIP SETPOINT Hot Applicable Hot Applicable Q 5.0 psig
+500 psig steam line pressure (100 psi with a time constant of 50 a 5 sec.
M 75K of narrow range instrument span each steam generator ALLOWABLE VALUES Not Applicable Not Applicable
~ 5.5 pslg
~ 480 psig steam line pressure
<110 psi with a time constant of 50 + 5 sec.
~ 76K of narrow range instrument span each steam generator a ~
l.
4.16kv Emergency Bus
+75% of nominal bus Undervol tage (Loss of Vol tage) vol tage with a 1
a 0.1 (Trip Feed) second time delay N 74% of nominal bus voltage with a 1
+ 0.1 second time delay 2.
4.16kv Emergency Bus (Start Diesel) b.
4.16kv Emergency Bus Undervol tage (Degraded Vol tage) c.
480v Emergency Bus Undervoltage (Degraded Voltage)
P83X - 12 cycles
+ 3X 90K -
OX of nominal bus voltage with a 90 x 5 second time delay
+ 3X 90K OX of nominal bus voltage with a 90
+ 5 second time delay g 89K of nominal bus voltage with a 90 a 5 second time delay
+89% of nominal bus voltage with a 90 a 5
second time delay
TABLE 3. 3-4 (Continued)
ENGINEERED SAFEZY FEA'IUBE ACTUATION SYSTEM INSTRUMENTATION TRIP SLTPOIhHS
&4H FUNCTIONAL UNIT TRIP SETPOIFZ ALUMABLE VAMP'.
AUXILIARYFEEDWATER a.
Steam Generator Water Level-low-low
~12% of narrow range instrument span each steam generator
~lit of narrow range instrument span each steam generator O
0 CA C
\\A IIM e4 b.
Undervoltage BCP c.
S.I.
d.
Turbine Driven Pump Discharge Pressure Low
> 468 psig
~ 452 psig
~ 2750 volts HCP bus voltage ~ 2725 volts HCP bus voltage See 1 above (all SI Setpoints) e.
Bnergency Bus Undervoltage f.
Trip of Main Feedwater Pumps
~3350 volts Not Applicable 53325 volts Not Applicable
~LE 3.3-5 (Continued)
ENGiNEERED ~~~ FEATURES RESPONSE TEES iNiT~G SITUS MK) r'UNCZICH
RESPONSE
T32K W SECONDS 11.
Steam Generator Water Level-Leer-lcm a.
Wtor-driven Auxiliary Fea2water Punps**
b.
Turbine-driven Auxiliary F~ter Pumgs***
60.0 60.0 12.
Undervolta e RCP a.
Turbine-driven Auxiliary Feaster Pumps 13.
Emer en Bus Undervolm e 60.0 a.
Motor-driven Auxiliary Feedwater Bergs 60.0 14.
Trim of Main Feaster:.Prmrns a.
Motor~iven Rniliary Feehrater Puris 60.0 15; Turbine Driven Pressure Lcw Dischar e a..
Motor-driven Auxiliary Feahmter Purrgs 60.0 Response ti~ for &Rotor-driven AuxiliaryF~ter Rmms,on all S.i. signal s~s
- 60. 0
- on 2/3 any Steam Generator
- on 2/3 in 2/3 Steam C~erators BEA~r V~K' UNiT 1 3/4 3-27a PROPOSED WORDiNG
TABLE 3.3-5 Continued TABLE NOTATION Diesel generator starting and sequence loading delays included
~
Response
time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps and Low Head Safety Injection pumps.
Diesel generator starting and sequence loading delays not included.
Offsite power available.
Response
time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps.
Diesel generator starting and sequence loading delays included.
Response
time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging
- PulllPS, (1)
Feedwater system overall response time shall include verification of valve stroke times applicable to the feedwater valves shown for penetrations 76, 77 and 78 on Table 3.6-1.
BEAVER VALLEY - UNIT 1
3/4 3-28 PROPOSED WORDING
TABLE 4. 3-2 (Continued)
ENGINEERED SAFETY FEATURE ACTUATION SYSTlM INSTRUMENTATION SURVEILLAhCE BHQUIBEMEDZS FUNCTIONAL UNIT CfRNNEL CHECK GIAN'NEL CALIDBATION GUNNEL
%UNCTIONAL MODES IN WHICH SURVEILLANCE REQUIRED 7.
AUXILIARYFEEDWATER a.
Stean Generator Water Level-l~-Lear b.
Undervoltage BCP S
R M
c.
S. I.
See 1 above (all SI surveillance requireaents) 1/ 2/
3 1/
2 d.
Turbine-driven Pump Discharge Pressure Iaw N/A e.
Emergency Bus N/A Undervoltage
. R 1/ 2/
3 1, 2, 3
f.
Trip of Main Feedwater Pumps N/A N/A 1, 2, 3
TABLE 4.3-13 (Continued)
RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUh1ENTATION SURVEILLANCE RE UIREhlENTS E
INSTRUMENT e.
Sampler Flow Rate ChlANNEL CHECK SOURCE CHECK N/A CHANNEL CALIBRATION CHANNEL FUNCTIONAL TEST CE CD O 4>
(/lW m~
CD I
D Ch K7 Ol CD 3.
Reactor Building/Supplementary Leak Collection and Release System (Rh'-VS-107A 8E 8) a.
Noble Gas Activity hIonitor b.
Iodine Sampler Cartridge c.
Particulate Activity Nonitor d.
System Effluent Flow Rate hEeasuring Device (FR-VS-112) e.
Sampler Flow Rate Vieasuring Device W(6)
N/A N/A N/A N/A N/A N/A H(5)
P(5)*** R(3)
Q(2)
N/A N/A 4.
Waste Gas Decay Tanks Honitor a.
Oxygen h1onitor (02-AS-GW-110-1,2) b.
Radiation htonitor (Rh1-GW-101) c.
Sampler Flow Rate Heasuring Device D**
N/A hi(5)
N/A Q(4)
R(3)
Q(2)
Q
TABLE 4.3-13 (Continued)
TABLE NOTATION During releases via this pathway During Waste Gas Tank filling operations During purging of Reactor Containment via this pathway (1)
The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway and control room alarm annunciation occurs if any of the following conditions exist:
a.
Instrument indicates measured levels above the alarm/trip setpoint.
b.
Downscale failure.
c.
Instrument controls not set in operate mode.
(2)
The CHANNEL FUNCTIONAL TEST shall also demonstrate that control room alarm annunciation occurs if any of the following cnditions exist:
a.
Instrument indicates measured levels above.
the alarm/trip setpoint.
b.
Downscale failure.
c.
Instrument controls not set in operate mode.
(3)
The initial CHANNEL CALIBRATION for radioactivity measurement instrumentation shall be performed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS.'hese standards should permit calibrating the system over its intended range of energy and rate capabilities.
For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration should be
- used, at intervals of at least once per eighteen months.
This can normally be accomplished during refueling outages.
BEAVER VALLEY - UNIT 1
3/4 3-67 PROPOSED WORDING
ATTACHMENT 8 SAFETY EVALUATION Proposed Change Request No.
97 amends the Beaver Valley Power Station, Unit No.
1 Technical Specifications Appendix A to correct the Radioactive Gaseous Effluent Monitoring and Engineered Safety Feature Instrumentation tables.
Descri tion and Pur ose of Chan e
1.
Table 4.3-13 has been revised to specify notation (2) applicable to the column Channel Functional Test for instrument 3.a.
Noble Gas Activity Monitor an instrument
.b.
Radiation Monitor (RM-GW-101)-,
since no automatic actuations are performed by these monitors.
Notation (3) has been revised by deleting the last sentence (Existing plants may substi-tute previously established calibration procedures for this require-ment),
since this was a
note in NUREG-0472 and should not have been included in the notation.
2.
Table 3.4-4, the functional -unit 4.e.
High Negative Steam Pressure Rate setpoint has been. corrected to include the time constant of 50
+
5 seconds.
3.
Tables 3.3-3, 3.3-4 and 4.3-2 have been revised to complete the list of signals that initiate the start of the Auxiliary Feedwater systems.
"Turbine Driven Auxiliary Feed Pump Discharge Pressure Low" was added to Functional Unit 7 "Auxiliary Feedwater".
4.
Table 3.3-5 has been revised to incorporate the response time applicable to "Turbine Driven Auxiliary Feed Pump Discharge Pressure Low" and revise table notation (1) to reflect Amendment 65 which revised the format of the Containment isolation valves on Table 3.6-1.
Basis l.
Is the probability of an occurrence or the consequence of an accident or malfunction of equipment important to safety as previously evaluated in the UFSAR increased?
No Reason:
1:
Table 4.3-13, table notation applicable to instrument items 3.a.
and 4.b.
have been revised to indicate control room alarm annunciation only since the monitors do not initiate any automatic actuation.
The Noble Gas Activity Monitor i,s described in the
I Safety Evaluation lA-Page 2
UFSAR Section 11.3.3.4 and shown in Figure 6.6.1.
Radiation Monitor RM-GW-101 is described in the.UFSAR Section 11.3.3.3.21 and shown in Figure 11.2-2.
These changes are consistent with the radiation monitor descriptions in the
- UFSAR, therefore, the probability of an occurrence or the consequence of an accident or malfunction of equipment important to safety will not be increased.
2.
Table 3.4-4, the Functional Unit 4.e. trip setpoint and allowable valve have been corrected to specify the applicable time constant and do not affect the UFSAR Section 7.3, Engineered Safety Features'ystem.
3.
Tables 3.3-3, 3.3-4 and 4.3-2 have been revised to reflect the Auxiliary Feedwater initiating signals described in UFSAR Figure 7.2-1, Instrumentation and Control System Logic Diagram, Sheet 14.
The Auxiliary Feedwater System and initiating signals are also addressed in and the proposed changes reflect the descriptions of UFSAR 'Section 7.3, Engineered Safety Features System; Section 7.4, Systems Required for Safe
- Shutdown, and Section 10.3.5, Condensate and Feedwater Systems.
4.
Table 3.3-5 has been revised to reflect the changes to the above tables and is consistent with the UFSAR Sections addressed above.
Table Notation note (1) is an editorial change to reflect the format change to Table 3.6-1 and does not affect the UFSAR.
2.
Is the probability for an accident or malfunction of a different type than previously evaluated in the UFSAR created?
No Reason:
The proposed changes are administrative in nature and do not physically change plant safety-related
- systems, components or structures, there-
- fore, the changes will not create the possibility for a
new type of accident or malfunction of a different type than any previously evalu-ated in the UFSAR sections addressed above.
The changes have been made to reflect what is already presently described in the UFSAR accident analysis Section 14.1.8, Loss of Normal Feedwater, and Section 14.1.11, Loss of Offsite Power to the Station Auxiliaries (Station Blackout).
3.
Is the margin of safety as defined in the basis for any Technical Specification reduced?
No Reason:
The Technical Specification BASES for Section 3/4.3.3.9, Radioactive Liquid Effluent Instrumentation and for Section 3/4.3.2, Engineered Safety Feature Actuation System Instrumentation, will not be affected by the proposed changes; since none of the systems or components will be physically changed or their function altered in any way.
4.
Based on the above, is an unreviewed safety question involved'?
No
~I I
Safety Evaluation 1A-Page 3
Conclusion The proposed changes are administrative in nature and reflect the systems described in the UFSAR.
The changes do not involve physical change to any plant safety-related
- systems, components or structures, will not increase the likelihood of a malfunction of safety-related equipment, in-crease the consequences of an accident previously analyzed, nor create the possibility of a
malfunction different than previously evaluated in the UFSAR.
Based on the considerations
- above, the proposed changes have been determined to be safe and do not involve an unreviewed safety question.
P k
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