ML16207A679
Text
UFSAR Section 5.4
SOUTH TEXAS PROJECT UNITS 1 & 2 REACTOR COOLANT PUMP Figure 5.4-1 Revision 0
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SOUTH TEXAS PROJECT UNITS 1 & 2 REACTOR COOLANT PUMP ESTIMATED PERFORMANCE CHARACTERISTICS Figure 5.4-2 Revision 0
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50 100 150 200 REFERENCE TEMPERATURE (T-NDTr)-°F SOUTH TEXAS PROJECT UNITS 1 & 2 K ld LOWER BOUND FRAcTURE TOUGHNESS A533V (REFERENCE WCAP 7623) GRADE 8 CLASS1 Figure 5.4-3 Revision 0
Integral Steam Nozzle with ----
Flow Restrictor 18 - 20" Model F Style Primary Moisture Separators Single Tier Dryers
--- Two-16 Secondary-Side Manways..
Auxiliary FWNozzle ~
Elevated Feedwater Ring with lrr.l'll>ft"-'"t'"-f!B-
Broached Flat Contact 405 Stainless Steel -
Tube Support Plates (TSPs)
Two -2" Inspection Openings at Each TSP Broached Flat Contact 405 Stainless Steel Flow Distribution Balle Two - 18" Primary-Side Manways /
- Perforated Discharge Nozzles Main FW Nozzle Alloy 690 rt Tubes Full-Depth Hydraulic Expanded Tube/Tubesheet Joint SOUTH TEXAS PROJECT UNITS 1 & 2 STEAM GENERATOR FIGURE 5. 4-4 REVISION 11 L0999.C IT L0999.111
SECTION A-A SOUTH TEXAS PROJECT UNITS 1 & 2 STEAM LINE FLOW RESTRICTOR Figure 5.4-5 Revision 0
STPEGS UFSAR UFSAR FIGURE 5.4-6 Reference Orawing(s) SR169F20000#1 SR169F20000#2 Revision 5
NOTE THIS DIAGRAM IS A SIMPLICATION OF THE SYSTEMS INTENDED TO FACILATE THE UNDERSTANDING OF THE PROCESS FOR DETAILS OF THE PIPING VALVES INSTRUMENTATION ETC. REFER TO THE ENGINEERING FLOW DIAGRAM. REFER TO PROCESS FLOW DIAGRAM TABLES FOR THE CONDITIONS AT EACH NUMBERED POINT.
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- 2.
THE CCS CCW FLOW TO THE SAFETY IIIIJECTION PUMPS IS NOT APPLICABLE TO STl'.
SOUTH TEXAS PROJECT UNITS 1 & 2 RESIDUAL HEAT REMOVAL SYSTEM PROCESS FLOW DIAGRAM Figure 5.4-7 Revision 0
STPEGS UFSAR NOTES TO FIGURE 5.4-7 Modes of Operation Mode A: Initiation of RHR Operation Following reactor shutdown, the second phase of plant cooldown starts with the RHRS being placed in operation. Before starting the pumps, the inlet isolation valves are opened, the miniflow valves are opened, the heat exchanger flow control valves are set at minimum flow, and the outlet valves are verified open. The miniflow valves are manually closed when flow is established to the RCS cold legs. Should the pump flow drop below the low flow set point the pump will automatically be shut off and an alarm will sound in the control room.
Startup of the RHRS includes a warm-up period during which time reactor coolant flow through the heat exchangers is limited to minimize thermal shock on the RCS. The rate of heat removal from the reactor coolant is controlled manually by regulating the reactor coolant flow through the RHR heat exchangers. The total flow is regulated automatically by a control valve in each heat exchanger bypass line to maintain a constant total flow. The cooldown rate is limited to 100 Flhr based on equipment stress limits and a 120 F maximum component cooling water temperature.
Mode B: End Conditions of a Normal Cooldown This situation characterizes most of the RHRS operation. As the reactor coolant temperature decreases, the flow through the RHR heat exchanger is increased until all of the flow is directed through the heat exchanger to obtain maximum cooling.
Note: The Emergency Core Cooling System components shown on the process flow diagram are not used for normal residual heat removal operations. The process conditions associated with the Emergency Core Cooling System operation (location numbers 1 through 37) are presented in the notes to Figure 6.3-5.
Revision 7
STPEGS UFSAR NOTES TO FIGURE 5.4-7 (~ontinued)
VALVE ALIGNMENT CHARI Valve No.
Operational Mode A
A'
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101 0
0 0
102 p
p 0
103 p
p c
104 C*
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c c
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0 0
0 - Open C - Closed P - Partially Open
- During initiation, valve 104 is open until flow is established in the RCS.
Revision 0
STPEGS UFSAR NOTES TO FIGURE 5.4-7 (Continued)
MODE A INITIATION OF RHR OPERATION (SUB-SYSTEM WITH RC fUMP & CVCS LETDOWN)<l>
Pressure Temperature Flow Location<2 )
Fluid psig OF ga1/min< 3>
106 1b/hr 101 RC 400 345 3400 1.544 102 RC 409 345 3400 1.544 103 RC 488 345 3400 1.544 104 RC 464 345 1144 0.51 105 RC 461 144.4 1144 0.51 106 RC 461 144.4 744 0.33 107 RC 440 345 2256 1.034 108 RC 417 296 3000 1.364 109 RC 461 144.4 400 0.18 110 RC
<461 144.4 400 0.18
- 1.
During mode A operation one of the three RHR subsystems may be operating in the loop with the active reactor coolant pump.
In this situation the RHR pump must overcome the reactor coolant pump head in the cold leg piping.
Also, one of the subsystems (train A or B) may be supplying purification flow to the CVCS via the low pressure letdown path.
For convenience this operation is included in this mode.
- 2.
All location numbers not listed identify lines containing fluid at static conditions.
- 3.
At reference conditions 350°F and 400 psig.
Revision 0
STPEGS UFSAR NOTES TO FIGURE 5.4-7 (Continued)
MODE B END CONDITIONS OF A NORMAL COOLDOWN Pressure Temperature Flow Location°>
Fluid psig OF gal/min<2>
106 lbjhr 101 RC
- 3. g<3>
150 3400 1.69 102 RC 14 150 3400 1.69 103 RC 102.2 150 3400 1.69 104 RC 78 150 3400 1.69 105 RC 52.3 123.5 3400 1.69 106 RC
<52.3 123.5 3000 1.49 107 RC 27.2 150 0
0 108 RC 3.8 123.5 3000 1.49 109 RC 52.3 123.5 400 0.2 110 RC 52.3 123.5 400 0.2
- 1.
All location numbers not listed identify lines containing fluid at static conditions.
- 2.
At reference conditions 350°F and 400 psig.
- 3. It is assumed here that the RCS is at a vacuum condition equal to the vapor pressure of water at 150°F.
Revision 0
LocationCl>
101 102 103 104 105 106 107 108 109 110 STPEGS UFSAR NOTES TO FIGURE 5.4-7 (Continued)
MODE A INITIATION OF RHR OPERATION (SUB-SYSTEM NOT CONNECTED TO LOOP WITH RC PQMP RUNNING)
Pressure Temperature Flow Fluid psig OF galjmin'2 >
RC 393 345 3400 RC 403 345 3400 RC 488 345 3400 RC 469 345 1144 RC 466 144.4 1144 RC 466 144.4 744 RC 420 345 2256 RC 396 268.5 3400 RC 396 268.5 0
RC 396 268.5 0
106 lb/hr 1.544 1.544 1.544 0.51 0.51 0.33 1.034 1.544 0
0
- 1.
All location numbers not listed identify lines containing fluid at static conditions.
- 2.
At reference conditions 350°F and 400 psig.
Revision 0
RELIEF NOZZLE HEATER SUPPORT PLATE SPRAV NOZZLE LIFTING TRUNNION SHELL LOWER HEAD INSTRUMENTATION NOZZLE SUPPORT SKIRT SURGE NOZZLE SOUTH TEXAS PROJECT UNITS 1 & 2 PRESSURIZER Figure 5.4-1 0 Revision 0
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SOUTH TEXAS PROJECT UNITS 1 & 2 REACTOR VESSEL SUPPORTS Figure 5.4-12 Revision 0
wIDE FWIGE COUMIS OIRECTIOII OF THERMAL EX PAllS I OM SOUTH TEXAS PROJECT UNITS 1 & 2 STEAM GENERA TOR SUPPORTS Figure 5.4-13 Revision 0
COLD LEG TENSION TIE ROD CROSSOVER LEG SOUTH TEXAS PROJECT UNITS 1 & 2 REACTOR COOLANT PUMP SUPPORT Figure 5.4-14 Revision 0
PRESSURIZER SKIRT BEARING PLATE GROUT SOUTH TEXAS PROJECT UNITS 1 & 2 PRESSURIZER SUPPORTS Figure 5.4-15 Revision 0
BUMPER
't R.C. PUMP CROSS OVER PIPE STEEL BUMPER STEEL BUMPER BLOCK SUPPORT BLOCK SUPPORT SOUTH TEXAS PROJECT UNITS 1 & 2 CROSSOVER LEG SUPPORT Figure 5.4-16 Revision 0
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REACTOR SOUTH TEXAS PROJECT UNITS 1 & 2 CROSSOVER LEG VERTICAL RUN RESTRAINTS Figure 5.4-17 Revision 0
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ct. STEAM GENERATOR RESTRAINT BASE MAT q_ REACTOR VESSEL SOUTH TEXAS PROJECT UNITS 1 & 2 HOT LEG PIPE WHIP RESTRAINT Figure 5.4-18 Revision.O
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SOUTH TEXAS PROJECT UNITS 1 & 2 HOT AND COLD LEG PRIMARY SHIELD WALL PIPE WHIP RESTRAINTS Figure 5.4-19 Revision 0
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1000 2000 FLOW (GPM) 3000 4000 Residual Heat Removal Performance Curves SOUTH TEXAS PROJECT UNITS 1 & 2 RESIDUAL HEAT REMOVAL PUMP PERFORMANCE CURVES Figure 5.4-20 Revision 0