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
ROC="ST:-2 G9S.~ND:-"-C RIC CORPCR TICN G~~iVA S:='~
ON CO:I RQ~'D COFZ K~SU.
G l N i'4 ~ 674 t iC iN UibfT =,i COMr t =
< =D DAir.'-
Ttir<E: ~
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::-'>>
12/3/79 Cod~
P-8
~ 0 mal,f~
e
\\
I Atty
~ '~P 12-
-7
': v.'i-3A
. C: -=GO2.-
/. O
'h/t %fQ
\\ ~
~
~'v'4 2 Sv
'e
~ 0 iq f 5 SLING
~
I
~
w m
wt 1
~
I 8003060 GQ
f
~I 1.0 IMMEDIATE ACTION AND DIAGNOSTICS FOR SPURIOUS ACTUATION OF SI, INCAt LOSS OF SECONDARY COOLANTg AND STEAM GENERATOR TUBE RUPTURE 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.
1.1.1 1.1.2 1.1.3 1.1.4 1.1.5
-.1.6 1.1.7 1.1.8 1.1.9 1.1.10 l.l.ll 1.1.12 1.1.13 1.1.14 1.1.15 1.1.16 1.1.17 1.1.18
..1.19 1.1.20 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):
Lmr Pressurizer Pressure Low Pressurizer Water Level High Pressurizer Water Level High Containment Pressure High Containment Ra3iation High Air Ejector Radiation High Steam Generator Blowdown Radiation Stean Flow/Feedwater Flow Mismatch Letdown Isolation/Pressurizer Heater Cutout Reactor Coolant Low Tavg Loop A and/or Loop B High Contairment Recirculation Smp Water Level Low Steamline Pressure (one or all Steamlines)
Lcw Steam Generator Water Level Increasing Steam Generator Water Level Rapidly Changing Reactor Coolant System Average Coolant 'iinperature Increased Charging Flow High Steam Flow (one or all Steam Lines)
Increased Dumping of CV Recirc fan collectors High Containment Temperature 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 2.1.2 2.2 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.
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.
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
- 2. 2.3 2.2.4 2.2.5 Busses 14, 16, 17, 18 are energized and at approximately 480 volts.
Main Feedwater Isolation has occurred.
Containment Isolation has occurred (Alarm A26).
t 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 2.2.9 2.2.10 2.3 Containment Ventilation isolation has occurred (Alarm A25).
Contairment recirc fans running
& charcoal filters in service SI pump suction swap-aver if ( 10% BAST level, 825 A and/or B Cpen 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, decay'eat removal will be effected by automatic actuation of the steam 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 2.6 Whenever the Containment 30 psig pressure setpoint's reached verify that containment spray is initiated.
If not manually initiate contairxnent spray.
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 2.8 3.0 If this condition exists refer to SC-1.3A Notify appropriate personnel of the nature of the emergency.
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 3.1.2 All pressurizer spray line valves are closed 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.
3.7.4 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:
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 3.8 Water level in at least one steam generator is in the narrow range span.
THEN 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 3.13 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.
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 is < 50'F subcooled ~
SAFElY INJECZION MUST BE MANUALLYREINITIATED.
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 REACTOR TRIP OCCURRED?
EVALUATE NEED FOR MANUAL REACK)R TRIP IF tV RETURN TO NORSE OPERATION VERIFY RFAC1QR TRIP MANUALLYINITIATE REACTOR IHIP HAS AUZCMATIC SI INITIATION OCCURRED?
EVALUATE NEED FOR MANUAL SI INITIATION IF N3 IF YES CQ TO E PRCCEDURE FOR Rx TRIP VERIFY SAFEGUARES SEQJENCE MANUALLY INITIATE SI GO 10 FIGURE 2 IMMEDIATE ACTIONS FIGURE 1
E
~ '
E-1.1:8 PRCS
< 1865 (RX TRIP?)
OR PRCS DECREASING?
K)OVAL PLANE ENVIRCR4ENZAL 6 RADIATION READ~
PRCS > 1715 psig MANUALLY
'IRIP ALL RCP's (0 TO E-1.4 SIELV ~'IQR
'IUBE RUETURE NO CCNZLINNENP INDICATION QQLNGES AND HIGH CCbIKNSOR AIR EJECKR RADIATION CR HIGH SG BIDWKSN IaDIATION PRCS
> 2000 PSI (AND IhCREASBK)
AND PZR~ IEVEL >
20%
AND AT IEAST CUE SG~ LEVEL IN NARKN PANGE SPAN AND
'IHE PCS SUKCOLING IS > 50oF G> TO E-1.3 DES CF SECCNDARY CCOIANP
~~'4INATE SAFEZY 24EC"ICN-
'IRANSFER 'IQ NBA~
PRESSURIZER
~SJRE
& LEVEL GÃZROL 03 TO E-1.2 IOSS CF COOIANP ACCIDEtG'O ABKR~~ OR INCREASING INDICATI(XJS EXIST EQR:
CONFAB"KNP PRESSURE CR CONIABRBK RADIATION CR CKZAINMEIZSIMP IEVEL McS PRCS DROP BEIOW mZ SI ACTUA ICV Sr~iINP OR PRESSURIZER L~r.L BEDE 10% OF SPAN?
CR
'CS
<: 50OF SUBCOOIED (D 'IQ E-1.3 IOSS OF SECCNDARY CCOIANr MANUALLYINITIATE SAFETY LVIECTICN REIURN 1Q FIGJRE 1
CD 'K)
E-P 'S FOR Bx
'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 4.1.2 MOV 825 AGB SI pump suction frcm the EST open 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 4.1.6 4.2
~.2.1 4.3 4 '
4.5 4.6 4.6.1 4.6.2 4.6.3 4.6.4 4.6.5 4.6.6
- MOV-841 and
- MOV-865, Accumulator discharge valves, are open MOV-1815A ard MOV-1815B, Safety Injection Pump 1C Suction Open Main feedwater pumps trip and discharge valves close.
Hain ard bypass feedwater control valves close.'oth diesel generators start.
Pressurizer control ard backup heaters trip.
All charging pumps trip.
If outside power is lost the following breakers tripped.
Screenhouse motor control centers breakers 1Gl and 1G2.
Mtor driven fire pump.
All circulating water intake heaters.
480V bus tie breakers 14-13, 16-14, 16-15, 17-18.
Instrument air canpressors.
All plant lighting except emergency DC lighting ard Emergency AC lighting supplied by the diesels.
4.6.7 C'omponent cooling water pumps.
(
-;.<.6.8 4.6.8.1 MCC 1C and MCC 1D loa3 shedding as follows:
Boric Acid Transfer pumps A and B.
4.6.8.2 Reactor Coolant Drain Tank pumps A an3 B.
4.6.8.3 4.6.8.4:
Reactor makeup water pumps A and B.
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.
4.8 C"
4.8.1 4.8.2 WEE:
Refer to RGaE Elementary 10905-118 for information to restore equipnent to service.
Containment isolation (T signal) will be generated and perform the following actions.
Trip the containment sump pumps.
Close the followirg isolation valves: (if open)
- AOV-371
- MOV-313
- HOV-813
- MOV-814
- MOV-996 A,EKC
- AOV-1728
- AOV-1723 AAOV-5392
- AOV-5738
- AOV-5737
- AOV-5735
- AOV-5736
- AOV-508 Letdown isolation.
Seal water return line isolation.
Reactor support ccoling inlet.
Reactor support cooling outlet.
Sample line isolation (outside contairment).
Containment sump pump discharge isolation.
Containment sump gmp discharge ~
isolation.
Instrument Air to containment isolation.
1A steam generator blowdown isolation.
1B steam generator bio&own isolation.
1A steam generator bio&own sample isolation.
1B steam generator blowdown sample isolation.
(RNV to Containment Isolation).
Contairnent ventilation signal the following actions:
will be generated ard perform Trip purge supply an) exhaust fans.
Close the following isolation valves. (if open)
"AOV-5869
- AOV-5870
~AOV-5878 "AOV-5879 AAOV-1597
+AOV-1598
- AOV-7970
- AOV-7971 Purge supply outside contairment.
Purge supply inside containment.
Purge exhaust inside contairment.
purge exhaust outside containment.
Radiation monitor supply valve..
Radiation monitor exhaust valve.
Contairxnent depressurization valve inside.
Containment depressurization valve outside.
p
(
contairment).,
Sample line isolation (pressurizer steam).
Sample line isolation (pressurizer liquid).
Gas analyzer line from PRT isolation.
N2 Supply line to accumulators.
RHR loop sample line isolation.
R.C. drain tank gas analyzer isolation.
R.C. drain tank vent header isolation.
R.C. drain tank vent header isolation.
R.C. drain tank pcs suction line.
R.C.D.T.
pump lA suction line.
R.C.D.T. punp 1B suction line.
D.I. water to C.V. auto isolation valve.
Demin. Water to Containment Isolation.
Containment air test supply valve.
Containment air test vent valve.
Contairment air test vent valve.
- AOV-953
- AOV-955
~AOV-539
- AOV-846 "AOV-959 "AOV-1789
- AOV-1786
- AOV-1787
- AOV-1721
- AOV-1003A'AOV-1003B
- AOV-8418
- AOV-8418
- MOV-ATV1
- NOV-ATV2
- llOV-ATV3 Additional containment isolation ard contairsnent ventilation valves, normally closed. (T-signal)
Check closed:
- AOV-951 Sam le line isolation outside
l I
<,wQL