ML17046A403
Text
TABLE 6.2-1 CONTAINMENT SPRAY SYSTEM - CODE REQUIREMENTS Component Code Spray Additive Tank ASME Section VIII Valves ANSI Bl6.5 Piping (including headers and spray nozzles) ANSI B31.l(l) pumps (1) For piping not supplied by the NSSS supplier, material inspections, fabrication and quality control conform to ANSI B31. 7.
Where not possible to comply with ANSI B31. 7, the requirements of ASME III-1971, which incorporated ANSI B31.7, were adhered to.
1 of 1 SGS-UFSAR Revision 6 February 15, 1987
TABLE 6.2-2 CONTAINMENT SPRAY PUMP DESIGN PARAMETERS Quantity Design Pressure, discharge, psig Design Temperature, °F Design Flow Rate, gpm Design Head, ft Shutoff Head, ft Motor, hp Type 1 of 1 SGS-UFSAR 2
250 150 2600 450
,..,530 400 Horizontal-Centrifugal Revi:>ion 6 Febrnary 15, 1987
TABLE 6.2-3 SPRAY ADDITIVE TANK DESIGN PARAMETERS Number Total Volume (empty), gal.
NaOH concentration, w/o Design temperature, °F Design pressure, psig Material 1 of 1 SGS-UFSAR 1
4000 30 300 14 Austenitic Stainless Steel Revision 6 Febr*1ary 15, 1987
TABLE 6.2-4 SINGLE FAILURE ANALYSIS - CONTAINMENT SPRAY SYSTEM Component A.
Spray Nozzles B.
Pumps
- 1) Containment Spray Pump
- 2) Residual Heat Removal Pump
- 3) Service Water Pump
- 4)
Component Cooling C.
Automatically Operated Valves:
(Open on two out of four (HiHi) containment pressure signals)
- 1) Containment spray pump discharge isolation valve D.
Valves Operated From Control Room (a) Injection
- 1) Spray Additive Tank Outlet Isolation Valve SGS-UFSAR Malfunction Clogged Fails to start Fails to start Fails to start Fails to start Fails to open Fails to open 1 of 2 Comments and Consequences Large number of nozzles render clogging of a significant number of nozzles as incredible.
Two provided.
Evaluation based on operation of one pump in addition to three out of five containment cooling fans operating during injection phase.
Two provided. Evaluation based on operation of one pump.
Six provided.
Operation of two pumps during recirculation required
- Three provided.
Operation of one pump during recirculation required.
Two complete systems provided.
Two parallel valves provided. Operation of one required
- Revision 6 February 15, 1987
Component (b) Recirculation
- 1) Containment Sump Isolation Valve
- 2)
Containment Spray Header Isolation Valve from Residual Heat Exchangers SGS-UFSAR TABLE 6.2-4 (cont)
Malfunction Fails to open Fails to open 2 of 2 Comments and Consequences Two lines in parallel.
One line required.
Two complete loops provided.
Operation of one required.
Revision 6 February 15, 1987
Component Spray Additive Tank Containment Spray Pumps (2)
Normal Operating Function None None TABLE 6.2-5 SHARED FUNCTIONS EVALUATION Normal Operating Arrangement Lined up for spray water diversion Lined up to spray headers Accident Function Source of sodium hydroxide for spray water Supply spray water to containment atmosphere Accident Arrangement Lined up for spray water diversion Lined up headers to spray Note:
Refer to Section 6.2 for a brief description of the refueling water storage tank, residual heat removal pumps, service water pumps, component cooling pumps, residual heat exchangers and component cooling heat exchangers which are also associated either directly or indirectly with the Containment Spray System.
1 of 1 SGS-UFSAR Revision 6 February 15, 1987
TABLE 6.2-6 NET POSITIVE SUCTION HEADS FOR CONTAINMENT SPRAY Minimum Maximum Flow and Suction Source Available Required Water Containment 86'-3" 2600 gpm RWST 29.9' 10' 100°F Spray Rated flow 101'-8" Residual Heat 46'-10" 4850 gpm Containment Sump 28.1' 22' Saturation Removal Recirculation 81'-8" (Unit 1 one Spray flow Pump operation)
Residual Heat 46'-10" 4850 gpm Containment Sump 25.7' 22' Saturation Removal Recirculation 81'-8" (Unit 2 one Spray flow Pump operation)
The available NPSH was calculated for the pumps indicated above using the following conservative assumptions:
- 1.
- 2.
- 3.
All calculations assume an empty refueling water storage tank.
No credit is taken for RWST fluid below 100°F.
No credit is taken for increased containment pressures following the LOCA.
l of 1 SGS-UFSAR Revision 24 May 11, 2009 I
TABLE 6.2-7 SINGLE FAILURE ANALYSIS -
CONTAINMENT FAN COOLING SYSTEM Component Containment Cooling Fan Service Water Pumps fl,utomat ically Operated Valves Malfunction Fails to start Fails to start Fails to operate as required 1 of 1 Five provided.
Evaluation based on three fans in operation and one contain-ment spray pump operating durlng the ection phase.
Six provided.
Two required for operation.
Five RCFC units are provided.
A failure of one valve to operate as required will result in no more than one RCFC becoming Evaluations have demonstrated that three RCFC units in oper-ation and one Containment Spray Pump operating, provide sufficient cooling during the injection phase of a
LOCA event.
Revision 18 April 26, 2000
Component Containment Cooling Fan Units (5)
Service Water Pumps (6)
SGS-UFSAR Normal Operating Function Circulate and cool containment atmosphere Supply river cooling water to fan units TABLE 6.2-8 SHARED FUNCTION EVALUATION Normal Operating Arrangement Up to four fan units in service Four pumps in service 1 of 1 Accident Function Circulate and cool containment atmosphere Supply river cooling water to fan units Accident Arrangement Five fan units in service Two pumps in service Revision 6 February 15, 1987
TABLE 6.2-9 SPRAY EVALUATION PARAMETERS Containment Pressure, psia Containment Temperature °F Injection Spray flow rate, gpm Recirculation Spray flow rate 1 Injection Spray pH Containment free volume, ft 3 Spray fall height, ft Minimum spray coverage gpm 61.7 271 2600 1900 8.5 to 10.0 2.6 X 106 116 0.75 Iodine spray removal coefficient A credited in radiological evaluation during s
injection phase:
A (hr-1 ) (OF< 100) elemental s
-1 A
(hr
) (DF < 50) particulate s
20 4.44 A credited during the transition from injection phase to recirculation phase s
(i.e., removal is not credited):
-1 A (hr
) elemental & particulate s
A credited in radiological evaluation during s
A.
(hr-1 ) (DF < 100) elemental s
A s (hr-1 ) (DF < 50) particulate A (hr-l) (DF > 100) elemental s
A (hr-1 )
s (DF > 50) particulate A
(hr -l) (>4 hours) particulate s
1 of 1 SGS-UFSAR 0.0 recirculation 14.6 3.24 0.0 0.32
0.0 phase
Revision 23 October 17, 2007
SGS-UFSAR TABLE 6.2-10 CONTAINMENT ISOLATION -
MAJOR PIPING PENETRATIONS THE INFORMATION CONTAINED IN THIS TABLE WAS RELOCATED TO THE SALEM TECHNICAL REQUIREMENTS MANUAL 1 of 1 Revision 25 October 26, 2010
TABLE 6.2-11 This page intentionally deleted 1 of 1 SGS-UFSAR Revision 16 January 31, 1998
TABLE 6.2-12 This Table has been deleted 1 of 1 SGS-UFSAR Revision 26 May 21, 2012
TABLE 6.2-13 This Table has been deleted 1 of 1 SGS-UFSAR Revision 26 May 21, 2012
TABLE 6.2-14 POST-ACCIDENT CONTAINMENT TEMPERATURE TRANSIENT USED IN THE CALCULATION OF ALUMINUM CORROSION Time Interval 0 - 300 300 - 1000 1000 - 2000 2000 - 4000
> 4000 SGS-UFSAR (sec) 1 of 1 Temperature (oF) 271 230 188 175 147 Revision 6 February 15, 1987
TABLE 6.2-15 INPUT PARAMETERS AND ALUMINUM INVENTORY PARAMETERS USED TO DETERMINE HYDROGEN GENERATION Plant Thermal Power Rating Containment Temperature at Accident Containment Free Volume Weight of Zirconium Hydrogen Generated by Zirc-Water Reaction Based on 2 percent value Based on 5 percent value Corrodible Metal 3575 MWt 120°F 2,500,000 tt3 47,946 lb 7,575 SCF 18,940 SCF Aluminum INVENTORY OF ALUMINUM IN CONTAINMENT (NUCLEAR STEAM SUPPLY SYSTEM)
Item Weight (lbs)
Source, Intermediate and Power 244 Control Rod Drive Mechanism Connectors 193 Paint 140 Contingency (Nuclear Steam Supply System) 250 Flux Mapping Drive System 122 Miscellaneous Valves 230 CRDM Ventilation System Fan Motor 71 Rotor [23] (Unit 1 & Unit 2)
Tri-band Antennas 4
Permanent Shielding (Carabiners) 175 1 of 1 SGS-UFSAR Surface Area (ft.£1 83 42 18,000 85 84 86 3
Revision 23 October 17, 2007
TABLE 6.2-16 CORE FISSION PRODUCT ENERGY AFTER 830 FULL POWER DAYS Core Fission Product Energy/ 1 Time After Reactor Trip Integrated Energy Re4ease Watt-Days/MWtx10-1 3.887 0.574 5
2.595
- 1. 777 10 2.211 2.967 20 1.760 4.934 30 1.475 6.541 40
- 1. 291 7.919 50 1.163 9.143 60 1.068 10.259 70 0.992 11.289 80 0.926 12.249 90 0.867 13.139 100 0.814 13.979 1 Assumes release of 50 percent core halogens +1 percent other fission products, includes 100 percent noble gases.
Values are for total (~ and y) energy.
1 of 1 SGS-UFSAR Revi~ion 6 February 15, 1987
Time After Reactor Trip Energy Release Rate 1
145 2
49.4 5
31.0 10 18.2 20 7.63 30 3.22 40 1.36 60 0.241 80 0.043 100 0.008 SGS-UFSAR TABLE 6.2-17 FISSION PRODUCT DECAY DEPOSITION IN SUMP SOLUTION 1 Percent Other Fission Products Energy Release Integrated Energy Release
_2 Watt-Day/MWtx10 Rate
_1 Watts/MWtx10 Release
_2 Watt-Day/MWtx10 4.27 3.78 0.536 5.88 2.90 1.18 6.65 2.59
- 1. 73 7.82 2.22 2.92 9.03 1.77 4.89 9.54 1.49 6.51 9.76 1.30 7.90 9.89 1.08 10.3 9.91 0.935 12.3 9.92 0.822 14.0 1 of 1 Total Energy Release Integrated Energy Rate
_1 Watts/MWtx10 Release
_3 Watt-Day/MWtx10 18.28 0.481 7.85 0.707 5.69 0.838 4.03 1.07 2.53 1.39 1.81 1.61 1.44 1.77 1.10 2.02 0.940 2.22 0.823 2.39 Revision 6 February 15, 1987