ML19351G305
| ML19351G305 | |
| Person / Time | |
|---|---|
| Site: | North Anna  |
| Issue date: | 02/19/1981 |
| From: | Sylvia B VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.) |
| To: | Clark R, Harold Denton Office of Nuclear Reactor Regulation |
| References | |
| 107, NUDOCS 8102230481 | |
| Download: ML19351G305 (14) | |
Text
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YzmonxrA ELECTRIC ann Pownw ConrAny R ic nwon n,Va mone :A 2020s February 19, 1981 Mr. Harold R. Denton, Director Serial No. 107 Office of Nuclear Reactor Regulation N0/DWL:ms Attn:
Mr. Robert A. Clark, Chief Docket No. 50-339 Operating Reactors Branch No. 3 License No. NPF-7 Division of Licensing U. S. Nuclear Regulatory Commission Washington, D. C.
20555 Gentlemen:
NORTH ANNA POWER STATION UNIT 2 SUBMITTAL OF INFORMATION REQUIRED BY LICENSE CONDITION 2.C.(14)
The attached information is provided in order to comply with license condition 2.C.(14) of the North Anna Unit 2 Operating License, NPF-7.
This information provides plant specific information for North Anna Unit 2 which is appropriate to develop the input information for system transient analysis computer codes.
It is our understanding that this information will be used by the Staff (or its consultants) to perform an auditory calculation of our currently submitted main steam line and feedwater line break analyses.
If there are any questions regarding this information, please contact us at your cor.venience.
Very truly yours, B. R. Sylvia Manager - Nuclear Operations and Maintenance Attachment ree -
cc:
Mr. James P. O'Reilly, Director g3.g:.:cr Region II ry Atlanta, Georgia 30303 g y s 17; g 93.3 ISS 1re, n-
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S3 U i;J; -
81022 3 Oy//
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ATTAC10!E!G SYSTEM SAFETY A'!ALYSIS DATA NORTH ANNA PO'JER STATION 1.
Power ratings (nominal and ESF) 2.
Non-fuci parameters to include a) Volumes in the RCS b)
Coolant t ransit time c)
Coolant temperatures (nominal) d)
Design flow rates e) Pressurizer info.
f)
Safety injection info.
g)
Stear generator relief and safety valve data.
3.
Nominal protection setpoints l'
s
NORT11 M;NA POWER RATINGS 1.
Nominal Full MSSS power 2' B5 E?t Core 2775 57t Pumps 10 M' t 2.
Engineered Safeguards design NSSS rating 2910 Mi't e
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PAGE 1
2.
MON TUEL PARAMETERS NORTH ANNA UNITS 1 AND 2 a)
Reactor Coolant System Volumes (includes
+3*/. to account for thermal expansion)-see also Table 1 1.
Total Volume (including pressuri=er steam space)
= 9823.9 cu. ft.
2.
Active Core Water Volume (inside baffle, bottom to top of active fuel) 512.9 cu. ft.
=
3.
Water volune to top of fuel (including douncomer)
= 1862.7 cu. ft.
4.
Water volume to no==le centerline 2496.3 cu. ft.
=
b)
Coolant Transit Time 1.
Maximum calculated power no g - T values calculated, see values in b)2 c
2.
Maximum Guarantee power (2775 MWT, 92800 gpm) transit time
,10.5 seconds
=
3.
No Load transit time 11.1 seconds
=
c)
Coolant Temperature (nominal) 1.
Maximum Guarantee power (2775 MMT and assuming 92800 gpm) a.
Thot = 613.8
'T b.
Teold 580.3
'T c.
Tave = 546.8
'T 2.
Maximum Calculated power Values not provided.
Use values shown in c)1 3.
No Load Tave 547.0
'T
=
d)
Reactor Coolant Pumps 1.
Nominal T1ourate flow per' pump 97,400 gpm
=
i 2.
Thermal Design T1ourate flow per pump 92800 gpm
=
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PAGE 2
e)
Pressuri=er Information (total values and por valve values indicated uhere applicable) 1.
Relief Valve Design Flourate and Tolerances two valves each passing a set pressure of 7335 psig nominal 179,000 t/hr
=
maximum
= 210,000 #/hr 2.
Safety Valve Design Flourate and Tolerances three valves each passing a set pressure of 2485 psig nominal 380,000 #/hr(3% accumulation)
=
3.
Spray Valve Design Flourate and Tolerances 315 gpm(3% accumulation) in each
=
of two valves 4.
Heater Design Capacity and Tolerances a.
total capacity 1400 HW
=
b.
control group 431 KW
=
c.
total of 4 backup groups:
2 a 115.4 MW e a 2-J 269.1 MW en 5.
Surge Line Triction Factor (including expansion and contraction losses)
P at specified flou = 20.1 psi J 30 cu. ft./ rec 6.
Internal Volume 1400 cu. ft.
=
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2 PAGE 3
f)
Safety Injection System 1.
Safety Injection Flourate (minimum safeguards for Steam Break)
See Table 2 for flourate versus reactor coolant pressure 2.
Time Delay to Start SIS open valves and start pumps after receiving initiating signal 12 sec.
=
(not including diesel start time) 3.
Diesel Starting Time start time 12 sec for steambreak
=
= 10 sed for quench spray actuation 4.
maximum concentration in piping 2100 ppm
=
minimum concentration in piping.= 2000 ppm b.
concentration in boric acid tank / boron injection tank minumim 20,000 ppm
=
c.
concentration in refueling water storage tank maximum 2100 ppm
=
minimum 2000 ppm
=
5.
SIS Volumes a.
piping from BIT to RCS =
20.5 cu. ft.
(cold leg injection only) cold leg insection - total volume (excluding BIT) including three injection lines and headers from one pump 30.7 cu. ft.
=
from tuo pumps 32.2 cu. ft.
=
longest run to one loop from pump 24.5 cu. ft.
=
b.
Boron Injection Tank (BIT) 900 gal
=
c.
Refueling Water Storage Tank (RMST) minimum =
475,058 gal maximum = 487,000 gal 6
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m
4 a
g)
STEAM GENERATOR RELIEF AND SAFETY VALVE INFORMATION i
Steam Flow at Full Power 0
Ib/hr (total) 12.12 x 10 Each steam generator is protected with five safety valves as follows:
1 Capacity, each Capacity, each Psig at at Set Pressure f
Mark No.
Set Press Set Press 1,135 Psig Tolerance SV-MS 101 A,B, C 1,085 817,883 855,084 11 %
SV-MS 102 A, B, C 1,095 825,323 855,084 11 %
SV-MS 103 A, B, C 1,110 836,483 855,084 1l %
SV-MS104 A, B, C 1,120 843,924 855,084 11 %
SV-MS 105A,B, C 1,135 855,084 855,084 11 %
Actual total capacity for 5 valves 4,275,420 lb/hr Required total capacity for 5 valves 4,252,439 lb/hr Excess apacity 22,981 lb/hr 1
Atmospheric Steam Relief Valves Number 3
(1 ' loon)
Setpoint, psig 1025 Capacity per valve, Ib/hr 425,244 1
0 e
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TABLE 1 VOLUMES AND ELEVATIONS Region Volume (ft )
Flow Area (f t )
Elevation at Bottom (ft)
Veritical licight (ft)
Upper plemum 898.2 41-7 8.165 11.00 Upper head 536.0 19.165 5.575 Hot leg / outlet nozzle (per loop) incl.
stop valve 150.2 4.59 10.62 2.815 S. 6. Inlet / loop 161.8 13.015
- f. 48 S. G. Tubes / loop
.789.4 11.1 20.495 34.79 S. C. Outict/ loop 161.8 13.015 7.48 Pump' Suction / loop 109.7 5.25 0.224 12.791 Pump (and thermal 83.5 6.0 6.974 barrier / loop Cold Leg and Inlet 110.02 4.125 10.682 2.292 Inlet Nozzle / loop Desncomer 57'.5 24.2 (average)
-5.21 23.0 J
Lower Plenum (Bottom of 900.
-14.573 9.363 vessel to bottom of fuel)
Core 571.7 41.5
-5.21 13.3 Core Bypass-(Between 215.
15.6
-5.21 13.375 Baf fic & Barrel)
Surge Line 30.2 0.721 13.036 9.884 Pressurizer 1400.
38.5 22.92 36.38
I TABLE 2: ETFAM BREAK SAFETY INJECTION FLORRATE MINIMUM SAFEGUARDS CASE one high-head punp delivering through three (3) injection lines,none are spilling; flow loss to the RCP soak injection lines which bypass the BIT isa considered.
RCS Hot Leg) Pressure (*)
(Psia Flou'to Core (GPM) 0.0 200.0 625.
400.0 602.
600.0 577.
800.0 550.
1000.0 523.
1200.0 495.
1400.0 466.
1600.0 436.
1300.0 403.
2000.0
- 368, 2200.0 328.
282.
- The hot les pressure is considered a good estimate.of the average
.RCS pressure with the RCPs running.
The cold legs are-50 psi higher-p5 essure than hot legs with the RCPs running.
0
r
- 3. Nominal Protection Setpoints MAIN TEEDLINE BREAM TACTORS LIMITING TRANSIENT SEVERITY:
MULTIPLE AUTOMATIC PROTECTION TEATURES Tenture Coincidence
_ Bypass Setpoint Requirements Condition reactor trip 2/3 none on pressurizer 2385psig high pressure reactor trip 2/3 none on pressuriner 92%
high level reactor trip 2/3 in 1/3 SG auto block w/ a on lo-lo SG loop isointed 15%
level reactor trip on 2/3 none variable overtenperature delta-t reactor trip 1/2 on 1/3 SG for none on stean/ feed flou and level mismatch coin-cident w/ low feed < steam by SG level 1616000lb/hr E level <25*;
reactor trip on any SI signal safety injection initiated-by:
- 1) high stone line 2/3 100 psi differential pressure
- 2) hi-1 containnent 17 psia pressure-e 4
FACTORS LI!11 TIN G TRJ.HSIENT SEVERITY:
MULTIPLE AUTOMATIC PROTECTION FEATURES Teature Coincidence Bypass Setpoint Requirements Condition motor-driven aux feed pumps start on:
1)lo-lo SG level 2/3 in 1/3 SG auto block w/
loop isolated 15%
- 2) opening of
' ~~
noin feed pump breakers 3)any SI signal
J 4
t turbine-driveis aux feed pump at H.T.
starts on same signals as notor pumps i
4 e
f t
Steam Line Break Automatic Protection Teatures Feature Coincidence
' Conditions for Nominal Setpoint Requirement Manual Bypas:
5 Source range hi 1/2 1/2 Int. range pi o-10 l
amps 10 cp, neutron 9 trip Int, range hi 1/2 2/4 power range channels current equiv.
r.eutron p trip
> 10% power to 25 t power d
Power range hi p trip low 2/4 2/4 power range channels 25 % power
> 10 t high 2/4 none 109 % power Overtemperature 2/3 none variable T trip Overpower T
2/3 none variable trip Low pressurizer 2/3 auto block / reset 9 P-7 JB70 psig pressure trip (3/4 P.R.
10% & 2/2 (lead / lag = 10/1) turb. imp pres.
10%)
Reactor trip on 1/2 SI nonc Saf ety Injecti 2n,
trains m
h e
+
+
Steam Line Break Automatic Protection reatures raature Coincidence Conditions for Nominal Setpoint Requirement Manual Bypass Sciety Injection Cn:
(1) low pressurizer 2/3 2/3 channels p-ll 1765 psig pressure (2000 psig)
(2) high stdam line 1/2 sig.
load depent.ent flow 2/3 lines with i
I (2a) low steam line 2/3 2/3 T ** <543 r
600 psig pressure (lead / lag =50/5)
EE (2b) lo-lo T,y, 2/3 2/3 T,y, < 5 4 3 r 543 r l
(3) High steam line 100 psi 6P (4) High containment 2/3 none 17 psia pressure I
1 l
l l
l L
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Steam Line Break Automatic Protection Features reature Coincidence Requirement Conditions for Manual Bypass Nominal Setpoint n:-
Steam line isolation on:
(1) high steam 1/2 signals line flow 2/3 lines load dependent yith (la) low steah 2/3 line pressure 2/3 T*** 4543 r 600 psig SE (lead / lag = 50/5)
(Ib) lo-lo T,y, 2/3 2/3 T,y, < 543 r 543 r i
(2) high contain-2/3 ment pressure none 20 psia Main feedwater isolation on:
Safety Injection reactor trip / low T,y, 554 r high S.C. level 75 t d
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