ML20053A287
| ML20053A287 | |
| Person / Time | |
|---|---|
| Site: | Fort Calhoun  |
| Issue date: | 05/11/1982 |
| From: | OMAHA PUBLIC POWER DISTRICT |
| To: | |
| Shared Package | |
| ML20053A183 | List: |
| References | |
| EP-29-1, NUDOCS 8205250173 | |
| Download: ML20053A287 (8) | |
Text
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(#h Fort Call.oun Station Unit No. 1 EMERGENCY PROCEDURE EP-29 Steam Line Rupture With a Complete Loss of Off-Site AC Power A.
PURPOSE To describe the steps to be taken if a steam'line rupture occurs in conjunction with a loss of off-site power.
NOTE:
If the offsite power low signal is received when a PPLS/
SIAS signal is in, the 4160V buses will load shed and re-sequence loads or the diesels.
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EP-29-2 a
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B.
SYMPTOMS
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1.
Any one or more of the following alarms may be present:
a.
Pressurizer level Lo b.
Pressurizer level Lo-Lo c.
Pressurizer pressure Lo 4
d.
Pressurizer safety injection signal Lo-Lo pressure TM/ Low Pressure channel trip e.
f.
Low pressure SG-2A channel trip g.
Low pressure SG-2B Channel trip 4
h.
SGLS circuit "A" actuated i.
SGLS circuit "B" actuated j
j.
Reactor trip k.
Safety injection actuation channel A 1.
Safety injection actuation channel B Low reactor coolant flow trip m.
4 Low 4160V and 480 Bus voltage alarms n.
2.
Any one or more of the folloing indications may be present:
a.
Rapid reduction in steam generator pressure b.
Increasing containment pressure i
i c.
Reduction in RCS temperature causing a corresponding decrease in pressurizer level and pressure d.
Steam generator level oscillations e.
Steam flow-feed flow mismatch f.
Change in generator electrical output g.
Noise if a steam line/ feed line rupture occurs outside containment h.
Loss of AC lighting and energization of DC emergency lighting R14 5-11-82 MAY t 11982
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EP-29-3 p
C.
IMMEDIATE ACTION
,.;y 1.
Depress the manual reactor trip pushbutton.
Insure that all regulating and shutdown CEA's have been fully inserted and that reactor power is decreasing.
2.
Insure turbine has tripped and all stop and intercept valves closed.
3.
Insure generator breakers 4 and 5 have tripped and that the generator field breaker has opened.
4.
Shut the MSIV's (Main Steam Isolation Valves).
5.
Insure the following functions have occurred and initiate those that have not by manual initiation:
a.
UG-1 and DG-2 should be at rated speed and voltage.
Breaker 1AD1 and 1AD2 should have auto closed, ener-gizing busses IA3 and 1A4.
If not:
b.
Insure normal and standby feeder breakers to 4160V safeguard busses are open.
c.
Insure load shedding on 1A3 and 1A4 except for 480V
@q Feeder Breakers.
NOTE:
Operator has the option of manually closing the breakers for the HPSI, LPSI, CS or FW-6 pumps with the control switch and with an undervoltage condition on the bus (es). However, with LPSI and FW-6 breakers closed in on the bus and the busses associated diesel breaker open, the auto closure of the diesel breaker is locked out.
D.
FOLLOW-UP ACTION 1.
If the Engineered Safety Features System was actuated:
a.
Insure safety injection flow is being delivered.
b.
Insure containment spray flow exists if CPHS occurred.
c.
Insure emergency boration of the RCS is taking place.
2.
If MSIV's closure did not terminate the transient:
a.
Find the affected steam generator (affected steam generator will experience a more rapid pressure decrease while the unaffected will be at the saturation pressure corresponding to the 'N'S temperature).
MAY 111982
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l EP-29-4 D.
FOLLOW-UP ACTION (Continued)
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b.
Secure all feedwater flow to. the affected steam generator.
3.
Insure RCS pressure is being maintained to achieve at least 50'F subcooling. RCS subcooling should not exceed 200 F.
a.
Throttle auxiliary feedwater flow to the unaf fected steam generator to aid in RCS pressure recovery, b.
Insure main feedwater isolation valves are closed (HCV-1385, HCV-1386) if CIAS occurred.
4.
Insure reactor coolant oil lift pumps are in operation.
5.
Check that turbine generator emergency DC oil pump and emergency DC seal oil pump in operation.
6.
Insure battery chargers are supplying DC busses #1 and #2.
7.
Verify natural circulation is being established in the RCS by:
CAUTION: Following a reactor trip and reactor coolant pump coastdown, T will nitially increase. When natural circulation begins, H
T will increase slightly, then peak. As natural circulation y
fIow rate becomes greater, T will decrease to a nominal T H
H
-u-for corresponding decay heat h$f a.
Core exit thermocouple temperatures are stable and at least 50*F below the saturation temperature for the existing RCS pressure as indicated on subcooled margin monitor.
b.
Core exit thermocouples and RCS hot leg temperature reading approximately the same.
c.
A AT across the core of not greater than 50 F, yet representative of the decay heat power level.
Immdediately after a 100% power trip, it is anticipated to be 20*F.
d.
Feed flow into the steam generator and steam flow out of the steam generator.
8.
Manually control DG-1 and DG-2 as required to maintain voltage and f requency at near rated conditions.
CAUTION: Ensure diesel generators are not overloaded.
9.
Refer to EP-4 for Loss of Flow, Follow-Up Conditions.
1 10.
If containment pressure is below 3 psig and containment air cooling /
filtering units are operating, refer to EP-35 to reset CSAS.
CAUT!ON:
Indicated water level relative to actual water level may be in
,.3
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f E) error due to the effects of varying fluid pressure and flashing h} 4,%g 0e of reference leg to steam on the water level measurements.
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EP-29-5 gb D.
FOLLOW-UP ACTION (Continued) 10.
(Continued)
Reference:
Technical Data Book, Pressurizer Level Correction, (III.l.b. - III.l.e.).
11.
Establish a water level in the pressurizer above the heater cutoff level and verify that the RCS is 50'F subcooled.
Secure the charging pumps to prevent the RCS pressure from exceeding that allowed by the cooldown curves. Proceed to EP-35 to terminate safety injection.
CAUTION: The charging and HPSI pumps are capable of overpressurizing the RCS during a ateamline break. The charging and HPSI pump operation should be regulated such that the cooldown curves of the Technical Specifications are not violated.
If the 100 F/hr cooldown rate curve is violated, RCS pressure shall be decreased to bring the pressure within the cooldown curve limit.
12.
Borate to cold shutdown margin unless emergency boration has already taken place.
13.
Feed the unaffected steam generator with an auxiliary FW pump via the emergency feedwater nozzles in a controlled manner as required to restore / maintain level at 80% or greater.
14.
Decay and RC pump heat can be removed by performing any one or more k@n of the following:
CAUTION:
Indicated water level relative to actual water level may be in error due to the effects of varying fluid pressure and flashing of reference leg to steam on the water level measurements.
Reference:
Technical Data Book - Steam Generator Level Correcton (III.3.a through III.3.g.)
Operation of the steam-driven auxiliary feedwater pump (FW-10) a.
with steam being supplied from unaffected steam generator.
NOTE:
If A steam generator has the rupture, ensure YCV-1045A is closed and open YCV-1045B.
If B steam generator has the rupture, ensure YCV-1045B is closed and open YCV-1045A.
b.
Periodic remote operation of the power-operated steam generator safety valve on the unaffected steam generator.
MS-291 for steam generator A MS-292 for steam generator B wg If steam line rupture was isolated by "MSIV" closure, heat could c.
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R14 5-11-82 MAY 111982 n
EP-29-6 gg D.
FOLLOW-UP ACTION (Continued) 15.
Attempt to restore offsite power to busses IA1 or IA2 and restart a reactor cootent pump in the unaffected loop per OI-RC-9 (Observe overpressurizattus precautions on OI-RC-9).
15.
Attempt to isolate the component causing the heat extraction.
17.
Refer to EP-1 for any applicable follow-up accions.
18.
If radioactivity above normal background is present in the steam generator secondary sides initiate the Site Emergency Plan and ensure that the Control Room is tenable by:
a.
Checking all access doors closed.
b.
Ensure that the control room ventilation system is in the filtered air makeup mode by placing the mode switch on the ventilation panel in the filtered air makeup mode, c.
Ensure a positive pressure exists in the Control Room (don respiratory protection if a positive pressure does not exist).
19.
Refer to EP-35 for Safeguards Reset.
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20.
Implement the Emergency Plan if appropriate. Refer to EPIP-OSC-1 for emergency classificatica and to EPIP-OSC-2 for the method of implementing the Emergency Plan.
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DISCUSSION fa,';e*,
r The major objective for eteam line break is to minimize the RC5 cooldown arid to ensure adequate reactor shutdown margin. To achieve this it is important to:
1.
Ensure that the Main Steam Isolation Valves (MSIV's) are closed. This will terminate the transient if the steam break occurred downstream of the MSIV's.
Closing the MSIV's ensures that only one steans generator can contri-bute to an uncontrolled heat extraction if the uncontrolled heat extraction is occurring upstream of the MSIV's.
2.
Secure the main feedwater isolation valves. This will terminate a feedwater line break downstream of FW isolation valves. Also, if the steam line break occurs upstream of the main steam isolation valves, the affected steam genera-tor will have to be boiled dry to terminate the transient.
If feedwater flow continues to the affected steam generater, the transient will continue.
3.
Verify that the RCS boron concentration is such that at least the cold shutdown condition is assured. Emergency botation by way of the CVCS can be utilized if required.
Emergency boration is automatically actuated if the Engineered Safety Features Syatem is actuated.
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