ML19317G893
| ML19317G893 | |
| Person / Time | |
|---|---|
| Site: | Rancho Seco |
| Issue date: | 10/14/1976 |
| From: | Mattimoe J SACRAMENTO MUNICIPAL UTILITY DISTRICT |
| To: | Reid R Office of Nuclear Reactor Regulation |
| References | |
| TAC-6710, NUDOCS 8004020551 | |
| Download: ML19317G893 (12) | |
Text
M nM 195 p
U.S. NUCLEAR REGULATORYO4MISStrN DOCKET NUM;E R -
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.m 50-312
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NRC DISTRIBUTION FoR PART 50 DOCKET MATERIAL
"[5 i* *"g TO:
FROM:
DATE OF DOCUMENT Sacramento Municipal Utility Dist.
10/14/76 Mr. Robert U. Reid Sacramento, California DATE RECEIVED J. J. Mattimoe
- 10/19/76 ETTER O NoToRIZ E D PROP INPUT FORM NUMBER OF COPIES RECEIVED j
%pHIGINAL kNCLASSIFIE D One signed U COP Y j
DESCRIPTION E N.C L.OSU R E Ltr. re our 8/11/76 ltr.... trans the following:
Furnishing an evaluation of the susceptability of the Rancho Seco Unit No. I reactor vessel to overpressurization events.
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REACTOR VESSEL OVERPRESSURIZATION j
DISTRIBUTION PER G. EECH 10-21-76
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Rancho Seco SAFETY FOR ACTION /INFORMATION 10/26/76 RJL k BRANCli CliIEF:
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$SMUD SACRAMENTO MUNICIPAL UTILITY DISTRICT O 6201 s street, Box 15830, sacramento, California 95813; (916) 452-3211 October 14,1976
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Director of Nuclear Reactor Regulation Attention: Mr. Robert W. Reid, Chief r
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. Operating Reactors, Branch 4 U. S. Nuclear Regulatory Commission u
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Washington, D. C.
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,,. Y Rancho Seco Nuclear Generating Nkq,%G Station, Unit No.1
Dear Mr. Reid:
You. letter of August 11, 1976 requested an evaluation of the susceptability of the Rancho Seco Unit No.1 reactor vessel to overpres-surization events.
This analysis has been performed and the evaluation is enclosed with this letter.
The Sacramento Municipal Utility District has determined that two changes are necessary to properly protect the reactor vessel from overpressurization.
The enclosed analysis is based on these two modifications.
A dual setpoint feature will be added to the pressurizer pilot actuated relief valve causing the valve to open at 550 lbs. pressure and close at 500 lbs. pressure during periods when the primary system temp-erature yields a maximum allowable reactor vessel pressure of 550 lbs.
Secondly, the Rancho Seco Unit No.1 operating procedures will be changed to require opening the circuit breakers for the motor operators of the four high pressure injection valves during plant cooldown prior to start-up of the decay heat removal system.
It is anticipated that both of these changes will be completed by the end of this year.
The District has previously installed a pressure and temperature recorder which operates over the full range of these parameters to verify compliance with Appendix G pressure temperature limits during start-up and shutdown as well as during plant operation, y"
y, Sincerely yours, Yh
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EVALUATION OF P0TENTIAL REACTOR VESSEL OVERPRESSURIZATION 1.
PURPOSE:
The purpose of this evaluation is to extmine the system design and operation for susceptability to overpre ssurization events during start-up and shutdown and to determine the pressure response of the Reactor Coolant System (RCS) to potential events which cause pressure increases.
1 2.
EVENTS EVALUATED:
The events examined in this evaluation were:
A.
Erroneous actuation of the High Pressure Injection (HPI) System.
B.
Erroneous opening of the core flood tank discharge valve.
C.
Erroneous addition of nitrogen to the pressurizer.
D.
Makeup control valve (makeup to the RCS) fails full open.
E.
All pressurizer heaters erroneously energized.
F.
Temporary loss of the Decay Heat Removal System!.s capability to remove decay heat from the RCS.
G.
Thermal expansion of RCS after starting an RC pump due to stored thermal energy in the steam generator.
3.
RESULTS OF EVENT EVALUATION:
3.1 General
For events which cause the RCS pressure to increase, the pressure will increase significantly faster in a " solid water" system than it will in a system with a steam or gas space.
The RCS always operates with a steam or gas space in the pressurizer; no operations involve a " solid water" condition, other than system hydrotest.
Considering the modest rate of pressure rise (because of non-solid pressurizer) from the events and the high level alarms in the pressurizer that would normally alert the operator, it is reasonable to expect the operator to terminate the event prior to reaching an overpressurization condition.
However, without operator action, the pilot actuated relief valve located on the pressurizer will terminate any pressure increase, thus preventing an overpressurization con-dition. A dual setpoint will be utilized for this valve to provide overpressure protection during start-up and shutdown conditions.
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The lower setpoint will be enabled by actuation of a switch in the control room during the plant cooldown prior to start-up of the Decay Heat Removal System at 280'F RCS temperature.
Characteristics of this valve at the lower setpoint are:
Open Setpoint 550 PSIG Close Setpoint 500 PSIG Steam capacity at 550 PSIG 25,985 lb/hr Equivalent liquid insurge volume rate into pressurizer 2,650 GPM Liquid capacity at 550 PSIG 500 GPM Nitrogen capacity at 550 PSIG 32,420 lb/hr Equivalent liquid insurge volume rate into pressurizer 2,350 GPM All events involving insurge to the pressurizer were evaluated with the pressurizer and makeup tank water levels initially at high levels.
For the pressurizer, a water level at the high high level alarm setpoint was used.
The relationship of this level to the other pressurizer water level setpoints is:
0"-320" Level indicating range 275" High high level alarm 220" High level alarm 180" Nonnal level
.160" Low level alarm 40" Low level interlock (heater cutout) and alarm For the makeup tank, which is the normal suction source for the maReup/HPI pump, a water level at the high level alarm setpoint was used. The relationship of this level to the other makeup tank level setpoints is:
0"-100" Level indicating range 86" High level alarm 73" Normal level 55" Low level alarm The initial pressurizer level used for the event does not affect the peak pressure reached; it only affects the rate of pressure increase.
3.2 Erroneous Actuation of the HPI System:
This event is not credible because the circuit breakers for the closed HP injection motor operated valves will be opened during c
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.p a plant cooldown prior to start-up of the _ Decay Heat Remval System. - These valves are shown on FSAR Figure 9.2-1.
3.3 Erroneous Opening of the Core Flood Tank Discharge Valve:
This event is not credible because this valve is closed and the valve control is tagged out during the plant cooldown before the RCS pressure is decreased to 600 PSIG.
'3. 4 Erroneous Addition of Nitrogen to the Pressurizer:
It is not credible that this event can overpressurize the RCS. Nitrogen is added to the pressurizer during plant cooldown at an RCS pressure of 50 PSIG or less. Nitrogen addition is controlled by a 50 PSIG regulator.
3.5 Makeup Control Valve (Makeup to the RCS) Fails Full Open:
This valve is on FSAR Figure 9.2-1 and is automatically controlled by the pressurizer level controller.
The pressure response of the RCS to this event is shown on Figure l'.
If it is assumed that the operator does not take action to teminate the event during the pressure increase, the peak RCS pressure is limited to 550 PSIG by the pressurizer pilot actuated relief valve.
Initial conditions used for the analysis were:
A.
275" pressurizer water level (high, high alann setpoint)
B.
86" makeup tank water level (high level alarm)
C.
32 GPM total seal injection flow to RC pumps (automatically controlled)
D.
45 GPM letdown flow from RCS to makeup tank i
E.
No spray into pressurizer (nonnally there would be).
Figure 1 depicts two pressure response curves. One is for an initial RCS pressure of 250 PSIG. This is the RCS pressure at which the Decay Heat Removal System is started up during plant i
cooldown.
Pressurizer water level would normally be about 180" instead of the 275" used in the analysis, The higher level used i
in the analysis increases the rate of pressure rise. The other pressure response curve on Figure 1 is for an initial RCS pressure at which the Makeup System would be in operation.
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. 1 Relief through the pressurizer relief valve will be terminated by operator action (stop makeup pump or close makeup line isolation valve) or without operator action when the makeup tank water volume is exhausted.
Peak insurge rate into the pressurizer is 360 GPM.
In addition to the alarms shown on Figure 1, other alarms and indications which would alert and aid the operator in evaluating the event are:
A.
Pressurizer high level alam(s) [with initial level below high high setpoint which would be normal].
B.
Higher than nomal makeup line flow rate indication.
C.
Lower than normal makeup pump discharge pressure.
D.
Full open indicating light for makeup valve.
E.
High temperature alarm for relief valve discharge line (after relief valve relieves).
F.
Higher than nomal RCS pressure indication.
G.
Higher than normal pressurizer level indication.
3.6 All Pressurizer Heaters Erroneously Energized:
The pressure response of the RCS to this event is shown on Figure 2.
If it is assumed that.the operator does not take action to terminate the event during the pressure increase, the peak RCS pressure is limited to 550 PSIG by the pressurizer pilot actuated relief valve. An initial pressurizer water level of 50 inches (10 inches above low level heater cutout interlock) was used because the lower water level results in the fastest pressure increase.
Even with the low level, the pressure increase is very slow.
The pressurizer water level will not change during this event as it is being automatically controlled.
The heaters are generating 1625 lbs. of steam per hour in the 500 to 550 PSIG range.
In addition to the alarms shown on Figure 2, other alarms and' indications which would alert and aid the operator in evaluating the event are:
A.
Higher than nomal RCS pressure indication.
B.
Higher than nomal letdown flow rate indication to makeup tank (due to, increasing RCS pressurizer).
C.
Higher than normal makeup line flow rate indication due to increasing letdown flow rate.
l D. -High temperatur alarm for relief valve discharge line
-(after relief valve relieves).
E.
The "On" indicating lights " lit" for all pressurizer heater banks.
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Relief through the pressurizer relief valve will be terminated by operator action (de-energize heaters).
Without operator action, the heaters will be de-energized when the pressurizer water level drops to the heater cutout interlock setpoint.
Since pressurizer water level is on automatic control, water is transferred auto-matically from the makeup tank to the RCS to replace that which is lost through the relief Valve.
For an initial makeu level at the high alarm setpoint, it would take six (6)p tank hours to empty the makeup tank and thus result in pressurizer water level decreasing to the heater " cutout" setpoint.
3.7 Temporary Loss of Decay Heat Removal Systems Capability to Remove Decay Heat From the RCS:
The pressure response of the RCS to this event is shown on Figure 3.
If it is assumed that the operator does not take action to terminate the event during the pressure increase, the peak RCS pressure is limited to 550 PSIG by the pressurizer pilot actuated relief valve.
Loss of decay heat removal capability could only be caused by loss of flow in the Decay Heat Removal System or in the cooling water system serving the Decay Heat Removal System.
Loss of flow.in either system would innediately actuate low flow alarm (s), thus alerting the operator.
Relief through the pressur-izer relief valve will be terminated by operator action restoring the decay heat removal function.
Insurge rate into the pressurizer is 98 GPM in the 500 to 550 PSIG pressure range. Conditions used in this pressure response analysis were:
A.
Event occurs during cooldown after start-up of Decay Heat Removal System and shutdown of steam generators.
B.
Pressurizer level at 275", normally it would be near 180".
C.
Cooldown to the Decay Heat Removal System " cut-in" temperature at 100*F/hr, this produces maximum decay heat generation rate.
D.
All scay heat absorbed by reactor coolant, no heat absorbed by the metal components or by the steam generators. Actually, these are heat absorbing sinks.
E.
32 GPM total seal injection flow to RC pumps (automatically controlled).
F.
45 GPM initial letdown from RCS to makeup tank.
1 G.
No spray into pressurizer.
3.8 Start of an RC Pump with Stored Thermal Energy in OTSG Secondary:
l Several postulated situations have been examined which n.ay lead to l
primary fluid expansion due to energy absorption from hot OTSG
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secondary water after start of an RC pump.
The two types of
(
situations which lead to possible RCS pressurization have been identified as follows:
Type A - Filling of 0TSG secondary side with hot water with subsequent start of an RC pump, and Type B - Restart of an RC pump (during heatup following a period of stagnant no flow) conditions.
3.8.1 Start of an RC Pump Under Type A Condition:
Figure 4 presents results of RCS the worst case Type A (see above) pressure versus time for condition.
Initial con-ditions for this transient are a result of filling.of, the steam generators with feedwater at 420 F.
This te~ perature m
is a result of the failure of the feedwater heating controls causing auxiliary steam flow to the heaters to produce a feedwater temperature in excess of the allowable value of 225 F for OTSG fill operations. The temperature of the feedwater in the OTSG secondary side following the filling operation reaches a temperature of 240 F as does the primary water contained in the RCS at elevations greater than the lower OTSG tubesheet.
This is a result of the heatin; of OTSG tubes and primary water during OTSG filling where heated primary water circulates to a limited extent through the RCS. At the end of the filling operation, the RCS water located below the OTSG lower tubesheet remains at the initial value of 140*F.
The primary system pressure versus time as shown in Figure 4 is based on an initial pressurizer level at the maximum value of the high high level alarm for a 177 FA plant.
The initial pressurizer level is normally kept much lower to minimize the heating requirements for raising the pressurizer temperature and pressure in preparation for starting an RC pump.
The initial pressure is 300 PSIG, the normal pressure required prior to starting an RC pump.
No credit has been taken for pressurizer level control.
The pressurizer level increased during tne transient by 30"; the level would have to rise an additional 70" before entering the upper head.
Other conditions of primary and secondary temperatures which may exist. prior to starting of an RC pumps have been evaluated and are bounded by the results of Figure 4.
These conditions include the situation where the feedwater temperature entering the OTSG's during filling operations is at the l
normal maximum value of 225*F but the operator fills the steam generators beyond the maximum allowable level and completely fills the steam generators.
In addition, the 4
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results presented here bound the case where the initial RCS temperature is 50*F before filling the steam generators.
3.8.2 Start of an RC Pump Under Type B Condition:
Figure 5 presents results of RCS the Type B conditions (see above) pressure versus time for Initial conditions for this transient are a result of the accumulation of pump seal injection and makeup injection water in the RC cold leg piping during stagnant (no flow) conditions.
Although the operator is required to initiate a cooldown of the RCS if RC pumps are inoperable and RC temperature >250 F (Plant Limit and Precautions), the assumption is made that the operator fails to do so while allowing makeup and seal injection water temperature to drop to 50 F, which is below the minimum value of ~RC temperature less 120*F.
The cold water is assumed to 'ccumulate in the RC cold leg piping without mixing with hot RC water.
The RC pumps is started following a period of one hour of stagnant (no flow) con-ditions in the RC System.
The primary system pressure versus tine as shown in Figure 5 is based on an initial pressurizer level at the maximum value of the high high level alarm for a 177 FA plant.
The initial pressure is 450 PSIG which is approximately midway between the Technical Specifications and RC pump NPSH pressure limits at 275 F.
No credit has been taken for pressurizer level control.
The decrease in pressure at approximately 2 minutes is a result of hot RC primary fluid entering a steam generator which has been cooled by the passage of the slug of low temperature RC fluid (the mixing of RC fluid and heat transfer through the OTSG tubing brings the RC fluid to a constant temperature and produces a net contraction of the fluid and a decrease in system pressure at final equilibrium conditions).
The pressurizer level increases during the transient by 13";
the level would have to rise an additional 87" before entering the upper head.
4.
CONCLUSIONS:
The preceding evaluation and analys.is demonstrates that the reactor vessel is protected from overpressurization during events which cause increasing pressure.
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