ML17249A734
| ML17249A734 | |
| Person / Time | |
|---|---|
| Site: | Ginna  |
| Issue date: | 12/03/1979 |
| From: | Bodine J, Noon J ROCHESTER GAS & ELECTRIC CORP. |
| To: | |
| Shared Package | |
| ML17249A732 | List: |
| References | |
| E-1.1, NUDOCS 8003060613 | |
| Download: ML17249A734 (18) | |
Text
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2ROCEDK3"- NO. E-l.l 3 V. NO. 13 IMMEDIATE ACTION AND DIAGNOSTICS FOR SPURIOUS ACTUATION OF SI, LOCA, LOSS OF SECONDARY COOLANT, AND STEAM GENERATOR TUBE RUPTURE I:-C='~ C~ c" l::-'>>
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~ I IMMEDIATE ACTION AND DIAGNOSTICS FOR SPURIOUS ACTUATION OF SI, INCAt LOSS OF SECONDARY COOLANT g AND STEAM GENERATOR TUBE RUPTURE
1.0 SYlPlOMS
NOTE: The process variables referred to in this Instruction are typically monitored by more than one instrumentation channel. The redurdant channels should be checked for consistency Mile p rfoxming the steps of this Instruction.
The following symptoms are typical of those Mich may arise in a plant Mich is undergoing a loss of reactor coolant, loss of secondary coolant or steam generator tube rupture (one or more symptoms may appear in any order):
1.1.1 Lmr Pressurizer Pressure 1.1.2 Low Pressurizer Water Level 1.1.3 High Pressurizer Water Level 1.1.4 High Containment Pressure 1.1.5 High Containment Ra3iation
-.1.6 High Air Ejector Radiation 1.1.7 High Steam Generator Blowdown Radiation 1.1.8 Stean Flow/Feedwater Flow Mismatch 1.1.9 Letdown Isolation/Pressurizer Heater Cutout 1.1.10 Reactor Coolant Low Tavg Loop A and/or Loop B l.l.ll High Contairment Recirculation Smp Water Level 1.1.12 Low Steamline Pressure (one or all Steamlines) 1.1.13 Lcw Steam Generator Water Level 1.1.14 Increasing Steam Generator Water Level 1.1.15 Rapidly Changing Reactor Coolant System Average Coolant 'iinperature 1.1.16 Increased Charging Flow 1.1.17 High Steam Flow (one or all Steam Lines) 1.1.18 Increased Dumping of CV Recirc fan collectors
..1.19 High Containment Temperature 1.1.20 Low Feedwater Pump Discharge Pressure
7 4a lg 7
~ l NCTE The pressurizer water level indication should always be used in conjunction with other specified reactor coolant system indication.
to evaluate system conditions ard to initiate manual operator actions.
2.0 IMMEDIATE OPERATOR ACTIONS:
2.1 Conditions requiring reactor trip or safety injection may be characterized by a number of unusual situations ard instrument indications.
2.1.1 If the plant is in a condition for which a reactor trip is warranted and an autanatic reactor trip has not yet occurred, manually trip the reactor.
Refer to Figure 1 attached.
2.1.2 If the plant is in a cordition for Rich safety injection is warranted and an autcmatic safety injection has not yet occurred, manually initiate safety injection. Refer to Figure 1 attached.
2.2 Verify the followirg actions ard system status. If any of the following automatic actions have not occurred and are required, they should be manually initiated.
2.2.1 Reactor trip (all rods on bottom) and turbine trip (turbine stop valves closed) .
~ 2~2 Busses 14, 16, 17, 18 are energized and at approximately 480 volts.
- 2. 2.3 Main Feedwater Isolation has occurred.
2.2.4 Containment Isolation has occurred (Alarm A26).
t 2.2.5 Auxiliary Feedwater Panps have started ard the Auxiliary Feedwater System valves are in their proper Bnergency Alignment and are fully open or fully closed as appropriate.
2.2.6 SI a RHR Pumps have started and the monitor lights indicate that the Safety Injection System valves are in the proper safeguards position.
2.2.7 Service water pumps have started and indicate sufficient service water pressure.
2.2.8 Containment Ventilation isolation has occurred (Alarm A25).
2.2.9 Contairment recirc fans running & charcoal filters in service 2.2.10 SI pump suction swap-aver if ( 10% BAST level, 825 A and/or B Cpen 2.3 Verify the following:
2.3.1
~ ~ Safety Injection flow from at least one train is being delivered to the reactor coolant system when the Reactor Coolant System pressure is below the high head safety injection pump shutoff head. If not, attempt to operate
r l
equignent manually or locally.
2.3.2 Auxiliary Feedwater flow from at least one train is being delivered to the stean generators. If not, attempt to operate equipment manually or locally.
If these attempts fail, start standby aux. EW pumps per E-29.3.
NOTE: Only after stean generator water level is ) 25% in the narrow range should the Auxiliary Feedwater System Flow be regulated to maintain required level.
2.3.3 Verify that heat is being removed from the reactor plant via the steam generators by noting the following:
2.3.3.1 Automatic steam dump to the cordenser is occurring:
2.3.3.2 .Reactor coolant average tenperature is decreasing towards progranned no-load temprature.
NCE'E: If condenser steam dip has been blocked due to a control malfunction or loss of the "Cordenser'Available" condition, removal will be effected by automatic actuation of the steam decay'eat generator power-operated relief valves, or, if these prove ineffective, the steam generator code safety valves. In this event, stem pressure will be maintained at the set pressure of the controlling valve(s) and reactor coolant average temperature will stabilize at approximately the saturation temperature for the steam pressure being maintained.
2.4 Whenever the Containment 20 psig pressure setpoint is reached. verify that the Main Steam Isolation Valves have closed. If not, manually close the Main Steam Isolation Valves frcm the Gontrol Board.
2.5 Whenever the Containment 30 psig pressure setpoint's reached verify that containment spray is initiated. If not manually initiate contairxnent spray.
2.6 Check if conditions exists for Site Radiation Emergency (1 Rem/hour on any area monitor plus either Plant Vent Alarm or Containment pressure 30 psig.)
2.7 If this condition exists refer to SC-1.3A 2.8 Notify appropriate personnel of the nature of the emergency.
3.0 SUBSEQUENTÃ OPERATOR ACTION (ACCIDENT DIA~STICS)
(Refer to Figure 2 Attached) 3.1 Evaluate reactor coolant pressure to determine if it is low or decreasing in an uncontrolled manner. If it is low or decreasing, verify that:
3.1.1 All pressurizer spray line valves are closed 3.1.2 All pressurizer PORV's ard safety valves are closed If not, manually close the valves fran the Control Board if possible
('.>.1. 4 If pressurizer PORV(s) are open an3 cannot be closed, close the respective(s) block valve(s) 3.1.5 If the RCS pressure is above the low pressure reactor trip setpoint (1865) ard is stable or increasing, go to STEP 3.7 3.2 Stop ALL Reactor Coolant Pumps after the high head safety injection pump operation has been verified arxl when the narrow presurizer pressure is at <
1715 psig CAUTION: If the reactor coolant pumps are stopped, the seal injection flow should be maintained.
NOTE The conditions given above for stopping reactor coolant pumps should be continuously monitored throughout this instruction.
NOZE: Notify the NRC within one hour of an actuation of the safety injection system, autcmatic or manual, to protect the reactor coolant system. A canmunication channel shall be left open for continuous connunication with NRC.
3.3 IF the condenser air ejector radiation and/or generator blowdown radiation monitor exhibit abnormally high readings, AND contairment pressure, containment radiation and containment recirculation sump level exhibit normal readings, THEN go to E-l.4 "Steam Generator Tube Rupture."
IF the steamline pressure is abnormally lower in one steam generator than in the other steam generator, THEN go the E-l.3 "Loss of Secondary Coolant."
3.5 IF containment pressure, OR containment radiation OR containment recirculation sunp levels exhibit either abnormally high readings or increasing readings, THEN go to E-l.2, "Loss of Reactor Coolant".
NOZE For very small breaks inside the contairment building, the containment pressure increase will be very small and possibly not recognizable by the operator. For'very small breaks the containment recirculation sump water level will increase very slowly ard early in the transient may not irx3icate a level increase.
3.6 IF the containment pressure, containment radiation AND containment recirculation sump water level continue to exhibit stable readings in the normal pre-event range, with relatively low R S pressure, THER go to E-l.3 "Loss of Secondary Coolant".
3.7 In the event of a spurious safety injection signal, the sequence of reactor trip, turbine trip ard safeguavQs actuation will occur.
'ATE: 'Ihe ooerator must assume that the safety injection signal is non-spurious unless the following are exhibited:
Normal readings for containment temperature, pressure, radiation and recirculation sump level or reason for the difference known ard acceptable RID
t 3.7.2 Normal readings for auxiliary building radiation and ventilation monitoring or reason for difference known and acceptable AND 3.7.3 Nodal readings for steam generator blowdown ard condenser air ejector rad iation.
IF all of the symptoms 3.7.1 through 3.7.3 above are met and when the
~folloein 3 .7 .4 ~roucrh 3 .7 .7 are exhibited:
3.7.4 Reactor coolant pressure is greater than 2000 psig and increasing AND 3.7.5 Pressurizer water level is greater 20% AND 3.7.6 The reactor ccolant indicated subccoling is greater than 50'F per subcooling meters NOZE: As a backup to the subcooling meters the average of thermocouple (points 11,15,18,19 6 20) may be used with pressurizer pressure and the attached saturation curve to verify 50'F subcooling.
AND 3.7.7 Water level in at least one steam generator is in the narrow range span. THEN 3.8 Reset safety injection CAUTION: Subsequent to this Step, should loss of offsite power occur, manual safety injection initiation would be required to load the safeguards equipment onto the diesel powered emergency busses.
3.9 Following SI reset, stop all Safety Injection and RHR pumps ard place then in standby mcde and maintain operable safety injection flowpaths.
3.10 Place CV Sump A pumps in pull-stop position before resetting contairment isolation.
3.11 Place all containment isolation (T signal) valve switches in the closed position and manuall reset containment isolation by use of key switch.
(Refer to autcmatic actions in section 4 of this procedure for containment isolation valve nunbers) 3.12 Reestablish normal makeup and letdown (if letdown is unaffected) to maintain pressurizer water level in the nodal operating range ard to maintain reactor ccolant pressure at values reached Men safety injection terminated. Ensure that water addition during this process does not result in dilution of the reactor coolant system boron concentration.
3.13 Reestablish operation of the pressurizer heaters (refer to 0-8.1, "Restoration of Pressurizer Heaters to Maintain Circulation at HSD," if no RCP's are running). When reactor coolant pressure can be controlled by pressurizer heaters alone, return makeup and letdown to pressurizer water level control.
WZE: IF after securing safety injection and attempting to transfer to normal pressurizer pressure and level control, reactor coolant pressure drops below the low pressurizer pressure setpoint for safety injection actuation OR if pressurizer water level drops
below 10% of span, OR the reactor coolant systen SAFElY INJECZION MUST BE MANUALLY REINITIATED.
is < 50'F subcooled ~
The operator must rediagnose plant conditions ard proceed to the appropriate emergency instruction.
NOTE IF after securing safety injection and transferring the plant ta normal pressurizer pressure an3 level control, the reactor coolant pressure does not drop below the low pressurizer pressure setpoint for safety injection actuation AND the pressurizer water level remains above 10% span, AND the reactor ccolant indicated subcooling is greater than 50'F then go to the normal operating instructions.
E-l.l:7 HAS AN AUZC&IATIC EVALUATE NEED REACTOR FOR MANUAL IF tV TRIP OCCURRED? REACK)R TRIP RETURN TO NORSE OPERATION VERIFY RFAC1QR MANUALLY INITIATE TRIP REACTOR IHIP HAS AUZCMATIC EVALUATE NEED IF N3 SI INITIATION FOR MANUAL OCCURRED? SI INITIATION IF YES CQ TO E PRCCEDURE FOR Rx TRIP VERIFY MANUALLY SAFEGUARES INITIATE SEQJENCE SI GO 10 FIGURE 2 IMMEDIATE ACTIONS FIGURE 1
E ~ '
E-1.1:8 PRCS < 1865 (RX TRIP?) K)OVAL PLANE OR ENVIRCR4ENZAL 6 PRCS DECREASING? RADIATION READ~
PRCS > 1715 psig PRCS > 2000 PSI MANUALLY
'IRIP PZR ~
(AND IhCREASBK)
AND IEVEL > 20%
ALL RCP's NO CCNZLINNENP INDICATION QQLNGES SG ~ AND AT IEAST CUE LEVEL IN NARKN PANGE SPAN (0 TO AND AND E-1.4 HIGH CCbIKNSOR AIR 'IHE PCS SUKCOLING SIELV ~'IQR EJECKR RADIATION IS > 50oF
'IUBE RUETURE CR HIGH SG BIDWKSN IaDIATION G> TO ~~'4INATE SAFEZY E-1.3 24EC"ICN-DES CF 'IRANSFER 'IQ NBA~
SECCNDARY PRESSURIZER CCOIANP ~SJRE
& LEVEL GÃZROL ABKR~~ OR INCREASING INDICATI(XJS EXIST EQR: McS 03 TO CONFAB"KNP PRESSURE PRCS DROP BEIOW mZ SI E-1.2 CR ACTUA ICV Sr~iINP ACCIDEtG'O IOSS CF COOIANP CONIABRBK RADIATION CR CKZAINMEIZ SIMP IEVEL OR PRESSURIZER L~r.L BEDE 10% OF SPAN?
CR
'CS <: 50OF SUBCOOIED (D 'IQ E-1.3 CD 'K)
IOSS OF MANUALLY INITIATE E-P 'S SECCNDARY SAFETY LVIECTICN FOR Bx CCOIANr REIURN 1Q FIGJRE 1 'IRIP c'IGJRE "
4.0 AUTOMATIC ACTIONS:
- Bright white light indicates Ken valve is in safeguard position.
4.1 Boric acid tank supply to safety injection pumps *MOV-826A,B,C and D Closed.
4.1.1 MOV 825 AGB SI pump suction frcm the EST open 4.1.2 The t~ injection line valves to the reactor coolant cold legs
- MOV-878B, and *MOV-878-D. ~n.
4.1.3 Core deluge valves fran the RHR pumps *MOV-852A ard
- NOV-852-B. Open 4.1.4 The containment fan coolers service water valves AOV-*4561 and AOV-*4562.
Open (Status light only) 4.1.5 *MOV-841 and *MOV-865, Accumulator discharge valves, are open 4.1.6 MOV-1815A ard MOV-1815B, Safety Injection Pump 1C Suction Open 4.2 Main feedwater pumps trip and discharge valves close.
~.2.1 Hain ard bypass feedwater control valves close.'oth 4.3 diesel generators start.
4' Pressurizer control ard backup heaters trip.
4.5 All charging pumps trip.
4.6 If outside power is lost the following breakers tripped.
4.6.1 Screenhouse motor control centers breakers 1Gl and 1G2.
4.6.2 Mtor driven fire pump.
4.6.3 All circulating water intake heaters.
4.6.4 480V bus tie breakers 14-13, 16-14, 16-15, 17-18.
4.6.5 Instrument air canpressors.
4.6.6 All plant lighting except emergency DC lighting ard Emergency AC lighting supplied by the diesels.
C'omponent 4.6.7 cooling water pumps.
( 4.6.8.1
-;.<.6.8 MCC 1C and MCC 1D Boric Acid Transfer loa3 shedding as follows:
pumps A and B.
4.6.8.2 Reactor Coolant Drain Tank pumps A an3 B.
4.6.8.3 Reactor makeup water pumps A and B.
4.6.8.4: Refueling Nater Purification punp.
4.6.8.5 Spent Mel Pit pump.
4.6.8.6 Penetration coolie fans A ard B.
4.6.8.7 Reactor canpartment fans A and B.
4.6.8.8 Boric Acid Evap. Package.
4.7 Loss of normal feed to 480V bus 14 or bus 16 during safety injection will initiate service water isolation to non-safeguards equipment.
WEE: Refer to RGaE Elementary 10905-118 for information to restore equipnent to service.
4.8 Containment isolation (T signal) will be generated and perform the following C" actions.
4.8.1 Trip the containment sump pumps.
4.8.2 Close the followirg isolation valves: (if open)
- AOV-371 Letdown isolation.
- MOV-313 Seal water return line isolation.
- HOV-813 Reactor support ccoling inlet.
- MOV-814 Reactor support cooling outlet.
- MOV-996 A,EKC Sample line isolation (outside contairment).
- AOV-1728 Containment sump pump discharge isolation.
- AOV-1723 Containment sump gmp discharge ~
isolation.
AAOV-5392 Instrument Air to containment isolation.
- AOV-5738 1A steam generator blowdown isolation.
- AOV-5737 1B steam generator bio&own isolation.
- AOV-5735 1A steam generator bio&own sample isolation.
- AOV-5736 1B steam generator blowdown sample isolation.
- AOV-508 (RNV to Containment Isolation) .
Contairnent ventilation signal will be generated ard perform the following actions:
Trip purge supply an) exhaust fans.
Close the following isolation valves. (if open)
"AOV-5869 Purge supply outside contairment.
- AOV-5870 Purge supply inside containment.
~AOV-5878 Purge exhaust inside contairment.
"AOV-5879 purge exhaust outside containment.
AAOV-1597 Radiation monitor supply valve..
+AOV-1598 Radiation monitor exhaust valve.
- AOV-7970 Contairxnent depressurization valve inside.
- AOV-7971 Containment depressurization valve outside.
Additional containment isolation ard contairsnent ventilation valves, normally closed. (T-signal)
Check closed:
- AOV-951 Sam ple line isolation ( outside contairment) .,
- AOV-953 Sample line isolation (pressurizer steam) .
- AOV-955 Sample line isolation (pressurizer liquid) .
~AOV-539 Gas analyzer line from PRT isolation.
- AOV-846 N2 Supply line to accumulators.
"AOV-959 RHR loop sample line isolation.
"AOV-1789 R.C. drain tank gas analyzer isolation.
- AOV-1786 R.C. drain tank vent header isolation.
- AOV-1787 R.C. drain tank vent header isolation.
- AOV-1721 R.C. drain tank line.
pcs suction
- AOV-1003A'AOV-1003B R.C.D.T. pump lA suction line.
R.C.D.T. punp 1B suction line.
- AOV-8418 D.I. water to C.V. auto isolation valve.
- AOV-8418 Demin. Water to Containment Isolation.
- MOV-ATV1 Containment air test supply valve.
- NOV-ATV2 Containment air test vent valve.
- llOV-ATV3 Contairment air test vent valve.
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