ML20050E175
| ML20050E175 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 03/16/1982 |
| From: | Wethy C FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17212B505 | List: |
| References | |
| PROC-820316-01, NUDOCS 8204130095 | |
| Download: ML20050E175 (175) | |
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REVISION 3 j
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1.0 Title
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EICESSIVE REACICR CCOLANT SYSTI'.l LNACE
2.0 Aceroval
Reviewed by Plant Nuclear Safety Committee Approved by -
M d h 19 7-T PlantManager 19 Revision 8 Reviewed by Facility Review Gtoup MC : l, /.. 198 1 Accreved W #E//_'./M_. Plant Manager
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- 19Q 3.0 Puroese & Discussien: M 3.L This procedure provides instrue:1cus cc determine when excessive reactor coolant system leakage exists, and steps cc take to identify it and initiate corrective actions. Leaicage in extess rf charging pump capacity is covered in 0120042. LOCA.
3.1 A leak shall be assu=ed to exist until it is determed that the indicnt.1 leak cannet ba suscanciated anc chat no unsaie condition exists.
3,. 3 Technical Specifications: ,
3.3.1 Reactor coolant system leakage shall be 11=1ced to:
a No pressure bouhdary leakage. ,
- b. 1 GMP unidentified leakage.
- c. 1 GPM total primary-to-secondary lackage through.staan generators
- d. 10 G7M identified leakage from the reactor coolan systa=.
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- e. Leakage as specified in T.S. Table 3.4.6-1 for each Reactor Coolanc Systen Pressure Iso. Valve identified. in.
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Table 3.4.5-1. /P.T
- c. y # o9 3.3. 2. Applicability:
\\ gg g, Modes 1 2. 3 and.4.
hs 3. 3. 3. Action:-
\#/ a. With any- PRESSURE SOUNDARY LEAKAGE, be in at least ECT "M STANDBT within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and. in COLD SEDTDOWN within the fc11cving 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
- b. With any Reactor Coolanc System leakage greater than any one ci che.above limits, excluding PRESSURE SOUNDARY MArACE, reduce the leakage rate to within itmits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or-be in at least ECT ST.ANDY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN vithin the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
4.0 S m coms:
4.L Positive indications, in the- control room, of leakage of coolanc from the. reactor coolant system to the containment or other systems are provided by equipment which permits continuous conitoring of certain plant parameters and the activity of the other systems.
l
. Listed below is equipment which =ay alarm and indicate when excessive g l leakage is present: 1. ContM nrant air particulate nonitor , ,
l 2. Containment radioactiva gas nonitor.
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Page 2 of 4 JFy-NORMAL OPERA m G PRCCEDURE 10120031 .
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E 4.0 Sy=peces: (cone) .
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- 3. Ccmponent cooling liquid monitor ,
4 Condenser air ejector gas conitor
- 5. Steam generator liquid sample monitor
- 6. Plant vent radiacion monitor
- 7. Conta1= ment area.radiacion =enitors
- 8. High level, pressure or temperature in the quench tank
- 9. Eigh temperature reactor coolant relief or safety valve discharge line.
- 10. Low level in volume centrol tank
- 11. High level containment sump
- 12. Low pressurizer level
- 13. Eigh level component cooling water surge tank
- 14. High level reactor coolant drain cank
- 15. Safety or Relief Valve {s) open alarm - H.ll
- 16. High S1 Loop Header Pressure /R7
- 4. 2 Monitoring of the volu=e control cank level over a specific ;eri:d of time, unile system is at sceacy state
.iii al.so Av. avidence of a reaccoe coolant system leax.
4.3 Larger amounts of leakage can also be detected by the following conditions:
'l. Frequent sca'rting of scandby charging pump. .
. 2. Abnormal increases in the amcunt.of reactor coo 1 4nt' system makeup water. '
- 3. Large amounts of leakage into the containment area (or smaller amounts over longer periods of time), flowing into the conta1= ment sump, vould be indicated by the frequency of operacion of the sump pump, and by changes in contai ment sump level indicacion.
- 4. 4. Leaks from. the low pressure safecy injection icop could be indicated by one of the following devices:
- 1. fq61peanc listed in Section 4.1.
- 2. Increased frequency of operation of -Jte . Low Pressure Saiety Injection. pump room sump pumps'.
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Paga 3 of 4 OFF-NORMAL OPE 2ATING PRCCIOU32 10120031 REVISION d a-
- 3. O I struetions:
5.1 Immediate Automatic Action:
- 1. If the contM-nc CIS radiation monitors exceed the _- ~
l present alarm point level, the contain=ent isolation s hnal is activated.
- 2. A high radiation alarm actuated by the steam generator liquid blowdown sample monitor closes the steam generator blowdown valves.
- 3. A high radiation alarm from the component cooling system shifts the vent valve on the comeonent cooling water surge tank to the chemical drain tank.
- 4. Back up Charging Pumps start (if needed).
5.2 I:=ediate Operator Action:
- 1. Ueon receiving an indication and/or 212= cf retteer coolsat systen leakage, the control room operator will proceed to analyze the :.nformation available to him and cetermine as accurately as possible the magnitude and seriousness of the
, leak. ' .
. 2. If the leak rate is greater than the capacity o,f the operable charging pumps, carry out " LOSS OF REACTOR CCOLANT" Procedure
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- 0120042. .
5.3 Subsequent Action:
1 Af ter determining the magnitude of tha leak, evaluate all the infor=ation available from the control room instrumentation, se s=11 w the 1ccril enunre! incten=ents, to attert te identify the leak and determine its location.
- 2. After determining. type- and magnitude of the leak, consult Tednir =1 Specification. (see Section; 3/4.6.6) and take action as.specified.
- 1. Imolement the. Imergency ?*an as necessary in accordance with EPIP 3100021E, " Duties of the Emergency C.aordinator". /R8 4 If leakage into the quench tank is identified as power operated relief or safety valve leakage, then quench tank pressure. and level alarm setpoints may be adjusted higher so that the operator would be alerted to an increase in in-leskage.
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Page a of 4 ~~I ,
1 0FF-NORY.AL OPERATING PROCIDUF2t/ 0120031 ,- ,
, RE7!SION 3 6.0
Reference:
6.1 Technical Specifications 3/4.4.6
- 6. 2. FSAR, Sectien 5.0
- 7. 0 Reports and Records:
7.1 Nor:nal log ancries 4
7.2 Nuclear Planc Supervisor should ensure chat data is collected to submit an abnor:nal occurrence report, if required.
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Page 1 of 5 b
TLORDA ?CEA s LIGHT COMPANY ST. L"CII PLA:C JNIT 11 0FF NORMAL OPERATING ?RCCDURE 1500030 RE7TSION l -
1.0 Ti:le:
ACCDENTS INVOLVING NEW OR SPENT FUEL
2.0 Acoroval
Reviewed by the ?' Nuclear Safety Committaa %'M!d /7 19 7f.
Approved by ae ?lant Managerdr4'7A"/#2. / 7 19J_L.
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~ Revision 2 Reviewed by FRG m/M c- /t 19 3 't Approved by /dy/2h Plant / M.anager 3 - /.s - 19K 47
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3.0 Pureose and Discussion:
l 3.1 This procedure provides instructions :o be followed in :he event a new or spent fuel element is dropped or involvec in a collision i during fuel handling operations. '
3.2 Discussion
3.2.1 The dropping or collision of a new fuel ele =ent say-result in an' alpha radiation ha:ard if the fuel elenent cladding. ,
is breached and the uranius oxide fuel pellets are exposed l to the surrounding a:=osphers 3.2.2 3 reaching of the fuel element cladding should be assu=ed :o have accompanied an accident involving fuel until subsequent radiation sonitoring and sampling indicates that no radio-active release has occurred.
3.2.3 The damaging of a spent fuel elenent can resul: in a serious radiation ha:ard if :he integ 1:v of -he fuel red cladding is breached. The radiation hazard is caused by the release of :he fission produe gases Il31 Iel33, and Kr33, nor-mily held in the fuel red voids between :he -
fuel pellets and the cladding, to the containment or spent l fuel pit atmosphere. )
i 3.2.4 Cace the 1.n:.cial release of fission produce gases :hrough !
the breached cladding has occurred, further significant release of fission product gases from the fuel pellets themselves is not expected, due to :he low temperature of the fuel during fuel handling operations.
F0R INFORMATION 0NLY This document is not controlled. Before use, verify information with e controlled document, t
? age : of 5 a
P OFF NORMAL CONDC!CN PRCCIDURE 1500030, RE7. 2 )
ACCIDENT CWCL7TNG NE'4 OR SPE'C FUEL 1
1.0 Svnetoms
I 4.1 Damage :o a spent fuel alenent, the cladding of which has been , ,
breached, nay be accompanied by:
4.1.1 area process or containmene air high radiacion alarms.
4.1.2 Gas bubbles originating from :he damaged element.
4.2 The alpha radiacion hazard associated vich a damaged new fuel elemenc will not cause actuation of the area or process radiacion sonitor high radiation alar =s.
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Paga 3 of 5 i
0FF NORMAL CONDITICN PROCEDURE 1600030, REV. 2 J ACCIDENT INVOLVING NEW OR SPENT FUEL ,
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5.0 Instructions
5.1 I==ediate automatic actions: ,
""8 5.1.1 For damage to new fuel - NONE '
5.1.2 If damage to spent fuel occurred inside containment, then CIS actuation =ay occur.
3.1.3 Containment evacuation alarm may actuate.
5.2 I= mediate Operator Action:
5.2.1 Inform control center operator of the accident.
5.2.2 If the accident occurred inside the containment:
- 1. Sound the Containment Evacuation Alarm.
- 2. Stop EVE 8A or 83 cent. purge fans if running.
4 Evacuate the containment and check for personnel con-
'tamination.
- 5. Notify Health Physics to perform a complete radio-logical evaluation.
- 6. Monitor applicable process and area radiation monitor channels for an increase in radiation levels inside containment.
5.2.3 If the accident occurred in the Fuel Fool Area:
5.2.3.1 Evacuate the spent fuel pit and remain on the landing outside the north door until monitored for contamination.
5.2.3.2 Notify the Control Center Operator.
5.2.3.3 Monitor applicable Area Radiation and Process Monitor channels for an increase in radiation levels inside the Fuel Fool Area.
5.2.4 Notify the Duty Call Supervisor and the Health Physics Supervisor.
5.2.5 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator". R2
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Pags i of 5 0FF NORMAL CONDITION PROCEDURE 1600030, REV. 2 I ACCIDE'iT INVOLVING NEW OR SPENT FUEL
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5.0 Instructions
(Cont'd) j 5.3 Subsequent Action i
5.3.1 Accident occurring in the containment: 1 man
- 1. Health Physics shall evaluate airborne particulate and gaseous samples from the containment atmosphere, and survey the surrounding area.
- 2. If radiation levels or sampling results indicate that the damaged fuel element cladding has been breached resulting in release of significant radioactivity:
- a. Place the containment airborne radioactivity removal units in service, per OP 2000021.
- b. When airborne radioactivity levels have reduced to as low as practical, and when further recir-culation vill not significantly reduce t5e lavels further, obtain a new gas release permit for con-tainment purge and start HVESA or 8B and purge
. containment.
c.
Continue purging the containhent until the Health
- Physics determines that a safe re-entry can be ,
made.
- 3. If there are no indications that the fuel element cladding has been breached, re-establish the containment in accordance with OP 0530021 " Controlled Gaseous Batch Release to Atmosphere".
4 Upon verification by Health Physics that radiation levels in the containment are safe, refueling personnel shall enter the containment and visually inspect the spent fuel element for damage.
- 5. After visual inspection and upon approval by the Reactor Engineer, the element shall be transferred to the spent fuel pit and stored away from the remaining fuel elements.
5.3.2 Accident occurring in the spent fuel pool.
- 1. Health Physics shall evaluate airborne particulate and gaseous samples from the spent fuel pool atmosphere.
i Page 5 of 5 0FF NORMAL CONDITION PROCEDURE 1600030, REV. 2 '
ACCIDE'IT INVOLVING NEW OR SPENT FUEL I
h i
5.0 Instructions
(Cont'd.) j '
4 5.3 Subsequent Action (Cont'd.) j 5.3.2 (Cont'd.) l g,, ,
- 2. If radiation levels or sampling results indicate that the damaged spent fuel element cladding has been breached:
- a. Operate the fuel pool supply and exhaust fans to ventilate the fuel pool area.
- b. Continue ventilation and sampling the spent fuel pool atmosphere until Health Physics deter-mines that a safe entry can be =ade.
- 3. Upon verification by Health Physics that radiation levels in the spent fuel pool are normal, refueling personnel shall entar the spent fuel pit and visually inspect the spent fuel element for damage.
- 4. Af ter visual inspection and upon approval by the Reactor Engineer, the element shall be hoved and stored away
. from the remaining fuel elements in the spent fuel pool.
6.0
References:
6.1 FSAR, Section 9.1.4, " Fuel Randling System" 6.2 FSAR, Section 12.1 and 12.2, " Radiation Monitoring System" 6.3 FSAR, Section 16.3, " Refueling" 6.4 10CFR20, Appendix B, " Concentrations in Air and Water Above Natural Background" 6.5 St. Lucie Plant Radiation Protection Manual 7.0 Records, Reports, and Notifications: _ _ _
7.1 Log Entries I
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4 ST. L'!CIE PLA'r" ~!'T!! NO . 2 0F?-NCRMAL OPERATING ?ROCIDURE NO. 2-1600030 REVISION n
- 1. TITLE: Accidents Involving New or Soent Fuel
- 2. PRE?ARED ST: M. A. Perrv October 16 19 81
- 3. SU3COMMI'" EE REVIIW ST: Isk[ for F&L J -6 19 T2--
- 4. RE7IEWED 3Y FRG ON: / N 1 " c l' Ii 193 1
- 5. APPRO7ED 3Y: -
Ge lant Manager 2 ~/ / 19 [3 i
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- 6. REVISION REVIILb 3Y FRG ON: 19 7 APPRO7ED 3Y: Plant Manager 19 I FOR 1RFORMAT10N GELY m ..
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l FLORIDA POWER & LIGHT COMPANY e p ST. LUCIE PLANT UNIT NO. 2 "
2 0FF NORMAL OPERATING FROCEDURE 2-t 600030 $
REVISION 1
1.0 TITLE
ACCIDENTS INVOL7ING Nm OR SPENT FUEL
2.0 APPROVAL
Reviewed by E cd i Review Group M 4 e c. I1 I/ 19 O_'-
Approved by A-d Plant Manager 7 W/ 19 v
Revision Reviewed by FRG 19 Approved by Plant Manager 19 3.0 PURPOSE AND DISCISSION:
3.1 This procedure provides instructions to be followed in the event a new or spent fuel element is dropped or involved in a collision during fuel handling operations.
3.2 Disussion
- 1. The dropping or collision of a new fuel element may result in an alpha radiation hazard if the fuel elen.ent cladding is breached and the uraniun oxide fuel pellets ar,e exposed to the surrounding atmosphere.
- 2. Breaching of the fuel element cladding should be assumed to have accompanied an accident involving fuel until subsequent radiation monitoring and sampling indicates that no radioactive release has occurred.
- 3. The damaging of a spent fuel element can result in a serious radiation hazard if the integrity of the fuel rod cladding is b reached . The radiation hazard is caused by the release of the fission product gases Il31, 24133, and ~r85, normally held in the fuel rod voids between the fuel pellets and the cladding, to the Containment or Spent Fuel Pool atmosphere.
- 4. Once the initial release of fission product gases through the breached cladding has occurred, further significant release of fission product gases fram the fuel pellets themselves is not expected, due to the low temperature of the fuel during fuel l hand 11ng operations.
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Page 2 of 5 0FF NORMAL OPERATING PROCEDURE 2-1600030, REV. 0 . l ACCIDENT INVOL7ING NEJ OR SPENT FUEL
4.0 SYMPTOMS
l 4.1 Damage to a spent fuel element, the cladding of which has been breached, nay be accompanied by:
4.1.1 Area Process or Contalment air high radiation alarms.
4.1.2 Gas bubbles originating from the damaged element.
4.2 The alpha radiation hazard associated with a damaged new fuel element will not cause actuation of the Area or Process Radiation Monitor high radiation alarms.
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0FF NORMAL OPERATING PROCEDURE 2-1600030 REV. 0 ACCIDENT INVOL7ING NEW OR SPENT FUEL 5.0 INSTRUCTIONS :
5.1 Immdiate Automatic Actions:
5.1.1 For damage to new fuel - none.
5.1.2 If damage to spent fuel occurred inside Containment, then a Containment Isolation Actuation Signal (CIAS) may occur.
5.1.3 Contaiment evacuation alarm may actuate.
5.2 Immediate Operator Action:
5.2.1 Inform Control Room personnel of the accident.
5.2.2 If the accident occurred inside the Containment:
- 1. Sound the Contairment Evacuation Alarm.
- 2. Stop HVE-8A and HVE-8B (Containment Purge Fans) if running.
- 3. Verify FC7-2 5-1 through FCV-25-6 (Contair: ment Purge valves) have closed. ,
- 4. Evacuate che Contairnent itad check for personnel contamination. .
- 5. Notify Health Physics Department to perform a cceplete radiological evaluation.
- 6. Monitor applicable Process and Area Radiation Monitor channels for an increase in radiation levels inside Containmen t.
5.2.3 If the accident occurred in the Fuel Fool Area:
- 1. Evacuate the Fuel Pool Area and remain on the landing outside the north door until monitored for contamination.
- 2. Notify Control Room personnel.
3 Monitor applicable Area Radiation and Process Monitor channels for an increase in radiation levels inside the Fuel Pool Area.
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0FF NORMAL OPERATING PROCEDURE 2-1600030, REV. O ACCIDENT INVOLVING NCJ OR SPENT FUEL
5.0 INSTRUCTIONS
(Cont.)
5.2 (Cont. )
5.2.4 Notify the Duty Call Supervisor and the Health Physics Supervisor.
5.3 Subsequent Action:
5.3.1 Accident occurring in the Contaiment:
- 1. Health Physics personnel shall evaluate airborne particulate and gaseous samples from the Contalment atmosphere, and survey the surrounding area.
- 2. If radiation levels or sampling results indicate that the damaged fuel element cladding has been breached resulting in release of significant radioactivity:
- a. Upon recommendation of the Chemistry Department, verify the Continuous Contalment Purge Systs and its associated filter train is in service and adjust flowrate to the value prescribed by Chemistry Department personnel.
- b. khen airborne radioact;ivity levels have been reduced to a level that would allow a normal cont'ainment purge, obtain a new gas
- release pemit and start HVE-8A or HVE-8B to purge Containment.
- c. Continue purging the Contaiment until the Health Physics Department determines that a safe re-entry can be made.
3 If there are no indications that the fuel element cladding has been breached, re-establish the Containment in accordance with OPf0530021 " Controlled Caseous Batch Release to Atmosphere".
- 4. Upon verification by Health Physics personnel that radiation levels in the Containment are safe, refueling personnel shall enter the Conta1 ment and visually inspect the spent fuel element for damage.
- 5. Af ter visual inspection and upon approval by the Reactor Engineer, the element shall be transferred to the Spent Fuel Pool and scored away from the emaining fuel l elements.
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Page 5 of Sa g&. 1 0FF NORMAL OPERATING PROCEDURE 2-1600030, REV. O ,
ACCIDENT INVOLVING NW OR SPENT FUEL . / -
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5.0 INSTRUCTIONS
(Cont.) 4 I
1 l wm 5.3 (Cont. )
5.3.2 Accident occurring in the Spent Fuel Pool:
- 1. Health Physics Department shall evaluate airborne particulate and gaseous sanples from the Spent Fuel Pool atmosphere.
- 2. If radiation levels or sampling results indicate that the damaged spent fuel element cladding has been breached:
- a. Operate the Shield Building Ventilation Systen to provide filtered / monitored ventilation of the Fuel Pool Area.
- b. Continue ventilation and sampling the Spent Fuel Pool atmosphere until Health Physics personnel determine that safe entry can be made.
- 3. Upon verification by the Health Physics Department that radiation levels in the Spent Fuel Fool Area are normal, refueling personnel shall enter the area and visually inspect the spent fuel element for damage. *
- 4. Af ter visuai inspection and upon approval by the Reactor .
Engineer, the element shall be moved and stored away from the remaining fuel elements in the Spent Fuel Pool.
6.0 REFERENCES
6.1 FSAR, Section 9.1.4, " Fuel Handling Systan" 6.2 FSAR, Section 12.1 and 12.2, " Radiation Monitoring System" 6.3 FSAR, Section 16.3, " Refueling" 6.4 10 C7R20, Appendix B, " Concentrations in Air and Water Above Natural Background" 6.5 St. Lucie Plant Radiation Protection Manual 6.6 FSAR, Section 9.4.2 " Heating, A/C and Ventilation Control" 7.0 RECORDS. REPORTS. AND NOTIFIC ATIONS:
7.1 Nomal los entries.
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Page 1 of 21 TLCREA PCWER i LIGHI CCMPANT ST. LUCIE UNIT NO. 1 5 IMERGINCY PROCEURE 0120042 I
. "tTSION 21 j 4 10 ittle: 4 FO R INFCP.UATION O NLY LOSS OF REACTOR COOLMIT This document is r of controlled. Before use, verify information with a controlled document.
2.0 Acoroval
Reviewed by Planc Nuclear Safety Courni: ee
~
19 1 Approved by -
> Plant Supt.,
- 19__
Revision 12 R viya d by Faci 1* y Review Group Dge. /0 19'79 Approved by / A;m 2/ .anager h /T 19 7 /
Revision 13 Mefiewed by Fa'cill:7 Review Group 1. a . - 19 / .
Approved by @/fff/1//h. -
?lant P. anger Al. z. 4 19 Pe Revision 21 Reviewed by Facili:7 Review Group '77a d t 19d2 Approved by /CM////M ?lant Manager 7 - Zs - 1982 Q
3.0 Pu m 2nd Discussi:n:
3.1 Purpose.
, Ihis procedure provides inscruc . ions :o be followed in , he *
. event chac 2eakage from :he Reactor Coolant
- System is in excess of operable charging pump capact:7 .
3.2 A loss of coolant accidene is defined as any necnanism where
- he loss of coolant from the Reac or Coolant System exceeds the capac1:7 of the operable charging pumps. When conditions in the Reactor Coolant System degrade to che poinc that a Limiting Safety System Setting is approached the Reac:or Procactive System will initiace a reactor : rip, naking the reactor suberitical. This will stop :he produccion of sewer in the core. Cooling of the core however, nust continue to remove the considerable decay heat that remains. the Safecy Injection System automatically provides a flow of subcooled vacar to the core for decay heat removal. Failure to keep the core covered will result in overheating of the fuel, failure of the cladding, and a release of gross amouncs of fissio2 produe:s to the coneminment atmosphere.
The spectru:n of breaks which would cause a LCCA is frem approximacely a .2 inch diameter break up to a double-ended hoc leg rupeure. For an example: Analysis show thac the flow from an unrestricted .3 inch diameter break is approximately ISO gym at 22.50 psia. A najor concern for :hese s=all breaks is that the flow :hrough the break nay not be sufficient for decay heat removal. In chose circumstances it is imperative that a secondary heat sink be available. This in turn dictates
- he use of the Auxiliary Teedwater System as the nain f eed-water system is disabled due :o an SIAS.
I
Page 2 of 21 EMERGENCY PROCEDURE 0120042, REV. 21 LOSS OF REACTOR CCOLANT i
- I i
3.0 Purpose and Discussion (Cont'd) i 3.2 (Cont'd)
Operator actions should be directed toward ensuring proper =="
operation of the Safety Injection and Containment Isolation Systems, ensuring all automatic functions have initiated properly, and taking action to protect plant personnel. Long term action is directed toward placing the plant in a cold shutdown condition. For small breaks where the ECCS will maintain RCS volume and pressure, operator action must be directed toward establishing and maintaining subcooled condi-tions in the RCS during the cooldown to prevent void formation.
4.0 Symptoms / Precautions:
Pressurizer level may not always be a true indicator of RCS fluid inventory. Pressurizer steam space ruptures, reference leg failures, and reference leg flashing may cause indications which are contrary to true conditions.
All available indications should be used to aid in diagnosing the event since the accident may cause irregularitiep in a particular instrument reading. Critical parameters must be verified yhen one or more confirmatory indications are available. With the Subcooling Margin Monitor (SMK) operating normally, use the n6mograph on RTGB 104 in conjunction with the SMM to eliminate dependence on a single
- instrument. With the S$H inoperable, refer to the nomograph utilizing control room indicators such as TH0T, pressuri:er pressure, and incore thermocouples to determine the margin to saturation. Subcooling margin can also be determined by subtracting hot leg temperature from pressurizer tenperature (TE-1101) .
When establishing auxiliary feed flow to the steam generators, use steam generator levels as well as header flow rates to ensure each steam generator 1s receiving auxiliary feedwater.
The diagnostic chart on Page 20 may be of some value in analyzing parameters.
4.1 Reactor coolant system leak exceeds the capacity of the operable charging pumps.
4.2 Reactor trip (Theenal Margin / Low Pressure) 4.3 Safety Inj ection Actuation Signal and Containment Isolation Actuation signal.
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x Page 3 of 21 y .. -
, DERGENCT PROCEDURE 0120042, REV. 21 e LOSS OF REACTOR COOLANT 3- , ..
_. " ..w f 4.0 Symptons/Precautionq: q s' N* 4 ~ 4 Any'one or more of the following incications or alarms may be present:
w>
- 4. '. 1 Decreasing pressurizer pressure.
' 4.4.2 Increasing containment pressure and temperature.
' ~ -- 4.4.3 Rising water level in the reactor cavity sump.
4.4.4 High contninment radiation.
~
' ' ' ~
4.4.5 Decreasing or increasing pressurizer level, w
4.4.6 Quench tank high level.
s
'4.4.7... Quench tank high temperature. ,
4.4.3
- Quench tank high pressure. .
. 4.4.9 Tavg decreasing or at saturation temperature for~RCS pressure.
, , REV 16 4.4*.10 Safety *ot reli,ef valve (s) open alarm H-il.
CAUTION: Some instruments' (valve position, temperature pressura, level indication,'etc.) specified for use in this procedure have not been de .
signed for-long term post:LOCA conditions
,. ~ inside the containment. Therefore, the -
operator should be especially alert that the potential exists for erroneous indication after >15 minutes have elapsed following a LOCA event.
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m'.j EMERGENCY PROCEDURE 0120042, REV. 21 f, LOSS OF REACTOR COOLANT j'
5.0 Instructions
, s 5.1 Imediate Automatic Actions ; .
5.1.1 Reactor trip / turbine trip - -
i 5.1.2 Safety injection actuation signal s 5.1.3 Containment isolation actuation signal 5.1.4 Containment spray actuation signal 5.2 Immediate Operator Action 5.2.1 Carry out immediate operator actions for reactor trip per OP 0030130.
5.2.2 Af ter an SIAS caused by low reactor coolant system pressure and after it has been verified that all CEA's have been fully inserted for 5 seconds, stop all operating reactor coolant paps.
5.2.3 Ensure safety injection and containment isolation actuation signals have occured or initiate manually. ,
Ensure HPSI flow to the core when pressure decreases below the pump's shut-off head (s1250 psia).
~
- 5.2.4 Establish and maintain s' team geherator levels at 65% ~
with auxiliary feedwater system. s, CAUTION: Do not exceed 750F/hr cooldown race.
,\
5.2.5 If conditions permit, attempt to locate and isolate 5 the source of the leak. Possible leak locations include, tat are not limited to the PCR7's, the letdown line, and sample lines.
s 5.3 Subsequent Actions ,
Observe all available indications to determine conditions within .
i che RCS. Use SMM display, RCS hot leg temperature, RCS cold leg tempera- ;[
cure, incore thermocouple temperature, and RCS pressure to determine ;
if the RCS is subcooled or saturated. An increase in temperature above the saturation temperature for the existing pressure is 3 i, an indication of voiding in the RCS. If this occurs the operator 3 must ensure that the RCP's are turned off, the SIS is providing is j makeup to the RCS, and that the steam generators are removing 'r ' '
heat from the RCS. The operator may be assured that a heat sink _
is available by observing steam generator feedflow and steamflow, by indications that steam generator levels and pressures are being 3;'
controlled, and by observing that operation of the steam generators j
is maintaining or decreasing RCS temperature and pressure. .\
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?tge 5 of 21 i
) <w\
E:dERGINCT PROCC URI 0120042, E7. 21 LOSS OF REACTOR COOLANT .
4 5.0 Inst-accions (cone.)
N 5.3 (cone.)
i 3
iy g
0 5.3.1 Refer to Tabla I to ensure che proper operacion of engineered 3".
saf ety features as time and condicions permic.
M.
's
5.3.2 Implemen
che emergency plan as necessary in accordance T '
with EPI? 31000212, " Duties of the Emergency Coordinator". /R21 ,
,5 i )
5.3.3 Ensure that containment spray is actuated if containment s pressure exceeds 10 psig, and check che following:
.* 2 contement spray pumps ON
.s $
2 spray header inlet valves CPEN 4 Na0H admission valves CPEN t
. . NaOH flow indicacion in control a 30 gym room op post accident panel
~
~
a 5.3.4 When containment . pressure decreases to less chan 10 psig, scop IA and 13 containment spray pumps, close FC7 07-1A **
N ._
- N, w. and FC7 07-13, resec CSAS channels A and 3, and return 4;3 ) ' - containment spray. pumps and FC7 switches to che "auco"
( position.
s
- 3. 3.5 Within one (1) hour, but withou: excepcion no later chan i
,' one (1) hour stop RCS/3AMI boracion via che charging i pumps.
1 5.3.6 Concinue to ensure proper operacion of the safety 5 ' i injection system by checking flow races and S.I.T.
levels.
? '/ ? After any SIAS, operate che SIS ~ until RCS hoc and cold
\ les camperatures are ac least 500 7 below saturacion
![
, y' camperature for the RCS pressure and a pressurizer level
, \4 is indicated, unless the cause of the SIAS has been
., verified to be an inadvertene actuacion. If 500Y k-
" %/
- t) '
subcooling cannot be maintained after the system has been scopped, che high pressure injection system must
' :\3 be started.
't:%;g .
i 3 CAUTION: Mw pressure - camperature operating restrictions take precedence over requirements s
"I ~ Uy for operation of the high pressure injection U'W or charging system to achieve 50* subcooling during operation of the shutdown cooling
, \t system.
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Page 6 of 2 1 EMERGENCY PRCCEDURE 0120042, REV. 21 LOSS OF REACTOR CCOLANT 7'
5.0 Instructions (cont) .-
d 5.3 (cont) ;
[
1 J
5.3.7 Imple=ent the Emergency Plan as necessary in accordance j with EP 3100021E, "Outies of E=ergency Coordinator."
5.3.8 To allow potential ECCS area radioactive leakage and RCS sample water, collected in the ECCS area sumps to be m pumped to the Reactor Coolant Drain Tank inside contain=ent, perfdr::Lthe.fdlicving:
- 1. At the C.R.A.C. panel place the "ECCS Area Leakage System" control switch to the "RDT" position and ensure that:
HCV-06-9 "R.D. Pump Suction" closes HCV-06-7 " Sump Pump To EDT" closes HCV-06-8 " Sump Pump to RDT" opens
- 2. At RIGB 105 open A0V-6301 :nd A0V-6302 "RDT Cr.tst Isol" valves by placing the switches in reset, then open positions.
- 3. Ensure the C'.R.A.C. Panel Annunciator "ECCS Pump Room Leakage Valves Misaligned" is not lit.
- NOTE: The following valves are provided with "CIS-OVERRIDE" capability:
A0V-5200, 5203 " Reactor Coolant Sample" FCV-26-1, 3 " Containment Sample Supply" FCV-26-2, 4 " Containment Sample Return" A0V-6301, 6302 "RDT Containment Isolation" 5.3.9 Immediately prior to the receipt of the Recirculation Actuation Signal restore power to V3659 and V3660.
5.3.10 Commence RCS cooldown as soon as possible and in any case, within one (1) hour. Reduce steam generator pressure to <985 psig. (safety setting). Refer to OP 0030127, Reactor Plant Cooldown.
CAUTION: Ensure RCS is maintained in a subcooled condition.
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Pags 7 of 21 l
EMERGENCY PROCEDURE 0120042, REV. 21 LOSS OF REACTOR C001.Ahr 5.0 Instructions (cont) l 5.3 (cont)
I mens ;
5.3.10AIf steam dump to condenser is available, close the Atmospheric Steam Dumps, and begin dumping steam to condenser.
- 5. 3.10B If offsite power is lost, steam dump to atmosphere must be used for cooldown.
5.3.10C Continue auxiliary feedwater flow to the steam generators during cooldown.
5.3.10D Do not exceed the 750F/ hour cooldown race.
5.3.10E If the RCS pressure remains greater (af ter stabilization) than the shutoff head of the LPSI pumps, stop both pumps.
CAUTION: Feedwater is normally provided to both steam generators. Isolation of a single steam generator per OP 0120041 (Steam Generator Tube Leak / '
Failure) is mandatory if a steam generator tube rupture is detected in that generator to prevent lifting of the safety valves or reseat them if they have lifted. This action will also reduce the amount of radioactivity released. For small breaks in the RCS where steam generators are important for heat removal one steam generator must be used for this purpose even if primary to secondary leaks are detected.
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Page 8 of 21 i
7
.w i DfERGENCY PROCEDURE 0120042, REV. 21 LOSS OF REACTOR C00LAfff a .
1 5.0 Instructions (cont.) l l 5.3 (cont.) , ,
5.3.10 When the RWI level reaches 6 f t., ensure that at least one (1) containment spray pump is running. Open the necessarf valve (s) as indicated by pump conditions to provide cooled water from the shutdown cooling heat exchanger (s) to the HPSI pump (s) during recirculation.
MV-3662 S.D.C. to 13 and 1C HPSI pumps MV-3663 S.D.C. to lA HPSI pump This is the preferred line-up for long term cooling.
5.3.11 Ensure that Recirculation Actuation (RAS) occurs when the RWI level decreases to 3 ft. indicated - (4 ft.
from the bottom of the tank) and check the following:
2 LPSI pumps TRIP 2 Min 1 flow recire valves SHUR 2 Containment sump outlet valves OPEN CAUTION: Ensure HPSI flow to the core continues *
, af ter RAS.* Do not allow the HPSI pumps ,
to operate " dead-headed". HPSI shutoff.
head (no flow) 1250 psig.
5.3.12 Ensure V3659 and V3660 are closed, then de-energize the valves using key operated switches on RIGB 106.
5.3.13 If all HPSI pumps and charging pumps are operating and the HPSI pumps are delivering less than 75 gpm per pump, turn off the charging pumps one at a time and then HPSI pumps one at a time until only one HPSI pump remains operating. This will ensure that Mn4== flow require-ments will be met by the flow through the pump to the RCS for the smallest break size that results in a SIAS.
5.3.14 Monitor R. A.B. radiation levels and sump levels af ter RAS to detect safety injection system leakage. Even if leaks are detected at least one HPSI pump must remain in operation to provide flow to the RCS.
5.3.15 As soon as possible, but without exception, within ten (10) hours, hot leg injection shall be initiated to the core in conjunction with the existing cold leg injection being sustained by the HPSI pumps per Appendix A.
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Page 9 of 31 i
EMERCENCY PROCEDURE 0120042, RE7. 21 LOSS OF REACTOR COOLANT 5.0 Instructions (cont.) J 5.3 (cont.) ==
5.3.16 If the pressure and inventory control with the SIS cannot be established af ter eight hours and RCS pressure is less than 300 psig, continue the hot and cold leg injection.
NOTE: It may be necessary to fill the pressurizar solid to regain pressure control and to achieve 500F subcooling. If this is the case the HFSI discharge valves will have to be carefully throttled during the cooldown to reduce system pressure.
5.3.17 If pressure and inventory control with the SIS are established after eight hours and RCS pressure is greater than 300 psig, conduct one of the following activities.
The activities are listed in order of decreasing preference.
- 5. 3.17 A RCS pressure above 300 psig indicates that the system has refilled and subcool.ing has occurred. Verify this by checking the saturation pressure for the existing tem-perature. Realign the safety injection,
. system'for cold leg injection. Continue to maintain 'subcooling and reduce RCS .
. pressure to <268 psia for shutdown cooling ,
by reducing the flow delivered by the high pressure injection and charging pumps. While reducing pressure and after shutdown cooling is initiated, maintain RCS pressure with the charging pumps and/or the HPSI pumps to continue to maintain at least 500 subcooling, or CAITf!ON: If there is a high radioactirity level in the reactor coolant system, circulation of this fluid in SDC may result in high area radio-activity readings in the auxiliary building. The activity level of the RCS should be determined prior to initiating SDC ficw.
5.3.17 B Continue to remove decay heat using auxiliary feedwater and steam dumps if adequate condensate is available and (A) cannot be implemented, or 5.3.17C open pressurizer power operated relief valves and align the safety injection system for cold leg injection if (A) or (3) cannot be implemented.
1
,. To open the PORV's, pull two RPS pressurizer high
+ pressure trip unit bistables.
i Page10 of 21 i
EMERGENCY PROCEDURE 0120042. REV. 21 LOSS OF REACTOR CCOLANT i ,
5.0 Instructions (cont.) l 5.3 (cont.) 1 5.3.18. Place both Hydrogen Recombiners in service per Appendix 3.
5.3.19 If containment hydrogen concentration cannot be maintained below 3.5" as indicated on the contaitusent hydregen sample syster by two (2) hydrogen recombiners, then place the contairznant hydrogen purge system into operation per Appendix B.
6.0
References:
6.1 FSAR Chapters 4, 6, Appendix 6C, 7, 8, 9,15.
7.0 Records Required:
7.1 Normal Log Entries e
Page 11 of 21 EMERGENCY PROCEDURE 0120042, REV H LOSS OF REACTCR COOLANT APPENDIX A l l
HOT LEG INJECTION j l
,' r U
- l. Prerequisite (,,,
a) Recirculation actuation signal has been initiated and required automatic functions have occured.
b) RCS pressure <250 psia. If RCS pressure is greater than 250 psia, continue cool-down until less than 250 psia.
- 2. Precautions a) Observe suitable radiological precautions at manual operating stations.
b) Ensure a minimum flow path to avoid dead-heading the HPSI, containment spray, and LPSI pumps.
c) Containment spray pump flow shall not exceed 1500 GEM.
d)* LPSI pump ficw shall not exceed 3500 GPM.
- 3. Primary method of hot leg injecjion 'using LPSI pumps via hot leg suction line.
a) Ensure RCS/ containment AP less than 150 '
psid.
b) Select operable LPSI pump and use applicable valve lineup A LPSI operable B LPSI operable c) Shut V3207 and 3432 3206 and 3444 d) Open V3400 V3484 ;
e) Shut HCV 3615, 3625 HCV 3615, 3625 !
3635, 3645 3635, 3645 f) Open V3651 and 3652 V3481 and 34@0 g) Start LPSI 1A LPSI 1B h) Monitor flow FT3306 & 3332 FT3306 & 3322 i) Maintain minimum flow of 250 gpm NOTE: If power is lost to one set of SDC hot leg suction valves, notify electrical department to install jumpers.
(
Page 12 of 21 E4ERGENCY PROCEDURE 0120042, REV 21 LOSS OF REACTOR COOI. ANT I H
APPENDIX A (cont)
I r
'l
- 4. Alternate Method: Hoc leg injection using j _J{
HPSI pumps via pressurizer auxiliary spray, a) Stop charging pumps and shut V-2336, 2337, 2339.
b) Open V-2340 CVCS to HPSI Auxiliary header I connect.
c) Shut ISE-02-01 and I-SE-02-02, IB1 and 1A2 loop chargine isolation valves.
d) Shut PCV-1100E and F, pressurizer spray valves.
e) Unlock and open I-SE-02-03 and I-SE-02-04 auxiliary spray valves.
f) One HPSI pump (B or C) must remain available to recirculata water from containment sump to HPSI header.
, 1) To,use A HPSI pump for hot leg in-
, jection, shut valves HCV 3617.,,3627, 3637 and 3647 and maintain 61nimum
- flow of 200 gpm through auxiliary spray by monitoring charging flow indicator FT 2212.
- 2) To use C KPSI pump for hot let in-jection (A pump not available), unlock and shut MV3653 and open MV3655. Shut HCV 3617, 3627, 3637 and 3647 and maintain flow of 200 gpm through auxiliary spray by monitoring charging flow indicator FT 2212.
- 5. Secondary Alternate Method: Hot leg injection using CS pump via hot leg suction line a) Condition, RCS/ containment AP <150 psid.
b) With 1 B containment spray, pump running; open or check to be open V-3457.
c) Place HIC-3306 Keyswitch in the Auto position.
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Page 13 of 21 DERGENCT PRCCEDURE 0120042, REV 21 LOSS OF REACTOR COOLANT M !
APPENDIX A (cont) l
- 5. (cont) ,
d) With the keyswitch in Auto, take manual control of HIC-3306, and close FCV-3306.
NOTE: The 1 B containment spray pump is still supplying cooled water to the B HPSI pump, and is now aligned to the LPSI Header, except for the opening of HCV-3657.
e) Close .MV-3207 and MV-3432.
f) Open V-3400 g) Open V-3651 and V-3652, ('B' LP51 pump suction valves from 'B' Hot Leg).
h) Close HCV-3615, HCV-3625, HCV-3635, HCV-3645.
- 1) Slowly open HCV-3657, until flow shows on FT-3306. Adjust HCV-3657 to maintain a minimum of 250 gpm flow on FT-3306 and FT-3332 (Loop.131 LPSI flow transmitt,er).
j) Adjus't HCV-3616, HCV-3626, HCV-3636
- and HCV-3646 until their respective flow
. transmitters read <150 gpm.
k) Check the running amps on the 'B' HPSI and 'B' containment spray pump to be below red line.
- 1) HCV-3657 can now be opened more to increase flow to the 'B' Hot Leg.
CAUTION: Do not exceed 1500 gpm total flow on the 'B' containment spray pump.
Page l a o f 21,
- EMERGENCT PRCCT,URE 0120042, REV 21 LCSS CF REAC"'CR C001. ANT
h APPENDIZ 3
?I. ACING L RECCM3I'IER AND I
CONTA15 MENT'LPURGE IN SERVICE
- 1. Place recombiners in serrice cs tollows:
1A 13
- 2. Set the power adjust potentiometer at
. zero (ooo)
- 3. Check that power is available to the power supply panel by observing the
" power available" white light on the control panel is illuminated.
- 4. See the Power Out Switch on the control panel to ene "ON" position. The rec light on the switch wil' '" ** ata.
- 5. Gradually turn the Power Adjust potept-iometer to 70 K'4 as indicated on the Power Out 'Jactmeter.
- CAUTION: There is a lag in the noter reading, so turn the potent-iometer know slowly. Do not exceed 75 W.
- 6. Periodically check the temperature of the three thernoccuples using the t#.mperature channel sal ctor switch.
And, when the temperature reaches 1250#F, adjust the power adjust potentiometer to maintain temperature between 1250 F#
and 1400 F.
CAUTION: Do not let the temperature exceed 1400*F as indicated by the thermocouple readout.
4 Page 15 of21 EMERGENCY PROCEDURE 0120042, REV 21 1 LOSS OF REACTOR COOLANT APPENDIX 3 (cont) 1
- 2. Place containment H purge in service as follows:
2
- 1. Verify closed V-25-15 and 16 filter bypass valves.
- 2. Unlock and open V-25-14 and 13 suction isolation valves.
- 3. Open FCV-25-9 hydrogen purge suction flow control valve.
- 4. Open V-25-17 hydrogen purge discharge to vent stack.
- 5. Start HVE 7A or 7B.
- 6. Unlock and open V-25-11 and V-25-12 makeup air for hydrogen purge.
- 7. Modulate FCV-25-10 open as needed to maintain char-coal absorber temperature below alarm point.
CAUTION: Ensure that either HVE 10A or HVE 10B is running. ,
- 8. Periodically check the stack radiation monitoring system for increasing gaseous and particulate levels.
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Page 16 of 2' i
l EMERGENCY PROCEDURE 0120042, REV .21 '
. LOSS OF REACTOR C00LAVI m mm '
TABLE 1
, 2.0 Containment Isolation Actuation Siknal 2.1 Two shield Building Vent Fans (HVE-6A, HVE-63) ON*
2.2 Two Control Room Vent Booster Fans (HVE-13A, HVE-13B) ON
- a. 2.3 Two Letdown Isolation valves (V-2516, V2515) SHUT 2.4 Two RCS Sample Isolation Valves (V-5200. V-5203) SHUT 2.5 Four Pressurizer Sample Valves (V-5201, V-5202,.V-5204, V-5205) SHUT 2.6 One Instrument Air To Containment Isolation Valve (MV-18-1) SHUT
, 2. 11 Two Containment Sump Pump Discharge Valves (LCV-07-llA, LCV-07-113) SHUT 2.12 Four Steam Generator Slowdown Isolation Valves (FCV-23-3, .
FCV-23-5, FCV-23-4, FCV-23-6) SHUT 2.13 Two Steam Generator Blowdown Sample Isolation Valves .
(FCV"-23-7 and 9) SHUT 2.14 Two Reactor Drain Tank Discharge Isolation Valves (V-6301, V-6302) SHUT 2.15 Four Control Room Air Inlet Valves (FCV-25-16, FCV-25-17, FCV-25-14, FCV-25-15) SFRn?
2.16 Two Control Room Kitchen Air Exhaust Valves ,(FCV-25-24, FCV-25-25) cNUT 2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18,
,,c.
FCV-25-19) SHUT 2.18 Six Containment Radiation Sample Suction and Return Valves (FCV-26-2. 4, 6, FCV-26-1. 3, 5) SHUT 2.19 Primary Makeup Water Isol Valve (MV-15-L) SHUT 2.20 Two RCP Controlled Sleedorf Isol Valves (V-2505 and ISE-01-1) SHUT
- NOTE: Only one shield building vent fan is required, the other should be shutdown and kept in standby. Open FCV-25-13, Cross connect valve.
- NOTE: Due to the possibility of NAMCO position indication switch failure on the letdown isolation valves, V2515, V-2516, containment purge valves FCV25-3, FCV25-4, and radiation monitor isolation valves FCV26-1, FCV26-3, FCV26-5, perform the following on receipt of valid CIS.
- a. V2515, v2516: Close. valves using switch on RTC3, ensure valves closed by observing letdown flow, press, etc.
- b. FCV25-3, FCV25-4: Ensure other valves in the line are closed
. (FCV25-1, FCV25-2, FCV25-5, FCV25-6)
- c. FCV26-1, FCV26-3, FCV26-5: Close valves using RTGB switch, close
, manual valves at monitor cabinet, ensure no flow indication on monitor.
I L I
Page 17 of 21 EMERGENCY PROCIDURE 0120042, REV 21 F
, LOSS OF REACTOR COOIXI TABLE 1 3.0 Containment Snray Actuagion Signal
! 3.1 Two Containment Spray Punos ON l 3.2 Two containment Spray Header Inlet Valves (FCV-0J-1A, j FCV-07-1B) OPEN l 3.3 Four NAOH (Caustic) Admission Valves (FSE-07-1A, FSE-07-2A, FSE-07-lR, FSE-07-2B) OPEN 3.4 Verify Containment Spray Flow in FI-07-1A and FI-07-1E.
3.5 Verify NA0H (Caustic) Flow on Post Accident Panel "A" (FI-07-2, FR-07-2)
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Page 18 of 21 I
EMERGENCY PROCEDURE 0120042, REV 21 LOSS OF REACTOR COOLANT m.--
TABLE 1 4.0 Recirculation Actuation Signal OFF 4.1 Two LPSI Pumos 4.2 Two Safety Injection Miniflow Recire. Valves (V-3659, SHUT V-3660)
Two Containment Sumo Outlet Valves (MV-07-2A, MV-07-23) OPEN 4.3 4.4 Two WI Outlet Valves (MV-07-1A, MV-07-13) SHUT 4.5 Verify HPSI flow to core continues af ter PAS on FI-3321, FI-3341, FI-3311, FI-3331.
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Page 19 of 21 DERCENCY Ps0CEDURE 0120042, RE7 21 l LOSS OF REACTOR COOLA:ff '
l TABLE I !
5.0 Main Steam Isolation Signal I, 5.1 Two Main Steam Isolation Valves (HCV-08-lA, HCV-08-13) SHUT 5.2 Two Main Steam Isolation Bypass Valves (MV-08-1A, SHUT MV-08-1B) 5.3 Two Main Feedwater Pump Discharge Valves (MV-09-1, SHUT MV-09-2) 5.4 Two Main Feedwater Block Valves (MV-09-7, MV-09-8) SHUT O
a O
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Page 20 of 21 EMERGENCY PROCEDURE 0120042, REV 21 LOSS OF REACTOR COOLA!rr TABLE I 1.0 Safety Iniection Actuation Signal km l
1.1 Two HPSI Pumps OU l.2 Two LPSI Pu=ps ON 1.3 Four AUX HPSI Discharge Valves (HCV-3617, 3627, 3637, 3647) OpgN 1.4 Four HPSI Discharge Valves (HCV 3616, 3626, 3636, ,a 3646) nonr 1.5 Four LPSI Discharge Valves (HCV-3615, 3625, 3635, 3645) OPEN
. 16 Check proper operation of the Safety Injection System by the following means.
1.5.1 Check HPSI flow rates on: FT-3311, 3321, 3331, 3341.
1.5.2 Check LPSI flow rates on': FI-3312, 3322, 3332, 3342.
1.5.3 Check decreasing Safety Injection Tank Levels on: L1A-3311, 3321, 3331, 3341.
1.7 Two CCW Pumos ON 1.3 Two CCW Valves from SDC EK's (HCV 14-3A, HCV 14-3B). OPEN 1.9 Four Containitent Cooling Fans ON 1.10 Four CCW "N-Header" Isolation Valves (HCV-14-8A, 14-9, 14-8B. 14-10). SHUT 1.11 Four SIT Check "alve Laakoff Valves (V-3618, 3628. 3638, 3648). SHUT 1.12 Two R_.A.B. Main Supolv Fans (RVS-4A, 46) OM 1.13 Two ECCS Area Exhaust Fans (HVE 9A, 93) ON* -
1.14 .Eight Aux Bldg Da=pers (D-5A, 6A, 9A, 12A, 53, 63,
~
- 93. 12B) . SHUT 1.15 Four Aux Bldg /ECCS Pump Room Dampers (D-13,14, 15, 16) '
OPEN 1.16 Four Reactor Coolant Pump CCW Isolation Valvec (HCV-14-1. 14-2, 14-6, 14-7). SHUT 1.17 Two FWP Discharge Valves (MV-09-1: MV-09-2) SHUT 1.18 Two Feedwater Block Valves (MV-09-7 : MV-09-8) SHUT 1.19' Two Charging Pumps ON 1.20' Two Boric Acid Makeuo Fatos ON 1.21' Two Letdown Isolation Valves (V-2515; V-2516) SHUT 1.22 VCT Outlet Valve (V-2501) SHUT 1.23 Two Gravity Feed Valves (V-2508: V-2509) OPEN 1.1% Emergency Sora;e Valve (MV-2514) OPEN 1.25 Two Bam Pume Recire Valves (V-2510, V-2511) SHUT 1.2 & Blender Outlet Valve to VCT (V-2512) SHUT 1.27 Load Control Valve (MV-2525) SHUT 1.28 Boric Acid Header Discharge Valve (MV-2161) SHUT 1.29 Two Rx Cavity Sump Isol Valves (LCV 07-LIA; LCV 07-113) SHUT 1.30 Two Intake Cooling Water Pumos ON 1.31; Two ICW to TCU Ex Isol Valves (MV-21-2; MV-21-3) SHUT 1.32 'A' ICW Lube ICR Supply to CW Pumps (FLV-21-3A) SHUT 1.33. '3' ICW Lube ICR Sunolv to CW Pumos (FLV-21-1B1 9HTTT
- NOTE: Only one ECCS area exhaust fan is required, the other fan should be shutdown and kept in standby.
/R18
DREAK IDEtif f flCAil0ll -
. PRESSURIZER PRESSURE DECREASitiG OR ,
UNEXPLAltlED CilANGE Iti PRESSURIZER LEVEL
GEllERATOR PREd5URES A0ll0RilALLY L0li IN ONE STEAM GEllERAT0lt PftESSURES IlllTIALLY N0llMAL O!!
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FLORIDA ?CWER 5 LIGHT COMPANY '
ST. LUCII UNIT 41 ,
OfERGENCY PRCCIDURE 0360040 l l
REVISICN 3 '
i
1.0 Title
l W u, OPERATIONAL REQUIRDfENT FOR THE C'ERGINCY CCOLING WATER CANAL 2.0 Review and Acoroval:
RE7IZWED BY FRG.,CN: ) O- 8 19 N APPROVED 3Y d M VJ PLANT MANAGER /7 I k [ M 19 /
Revision 3 Reviewed by FRG M'ff,# M 199 2 Approved by ##. ////M Plant Manager ~2 -/S - 19h
3.0 Purpose
The Emergency Cooling Water System consists of a canal tonnecting 31g !!ud Creek to the intake in front of the circulating water intake structure. This secondary source will be used only in the event that the primary source from the Atlantic Ocean becomes inoperable.
For normal operation the barrier wall across the Ultimate Heat Sink (VES) separates -'- 4-take canal fr:= 31;; :".ud Creeh.
An operable URS ensures that sufficient cooling capacity is available ,.
to either,(1) .ptovide normal cocidown of the facility, or (2) to nitigate the effects of accident condit;ons within acceptable Metts.
4.0 Svuotoms
4.1 Intake structure low water level (Annunciator E-17) 4.2 Intaka local level indication less that -9 ft.
4.3 Intake water temperature high (TR-21-3) .
5.0 Instructions
5.1 The Operacious Supervisor shall determine the need to operate the UHS.
5.2 The Operations Supervisor shall notify the Duty Call Supervisor.
5.3 The turbine generator and associated equipment will be shutdown per OP 0030125.
5.4 The Circulating Water System shall be shutdown per OP 0620020, 5.5 Implement the Emergency Plan as necessary in accordance with EPIP. 3100021E, " Duties of the Emergency Coordinator". R3 FOR INFO!1t1ATl0N ONLY This document is not controlled..Before use, verify information with a controlled document. g
1 i
Page 2 of 2 !
DiERGEICT PRCCDURE 0360040, .El 3 OPEPATIONAL REQUIREiDrtS FOR THE E4EFGEICT COOLING WATER CAMAL
5.0 Instructions
(continued) 1 hun 5.6 The reactor shall be shutdown and placed is node 3.
NOTE: The Reactor shall be in mode 3 within one hour of (1) reaching an intake water level of less than
-10.5 f t or (2) an average gatake resperature of greater than or equal to 96 F.
5.7 Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after placing the Reactor in node 3, the flow barrier wall valves I-SE-37-L and I-SE-37-2 shall be opened providing cooling water from 31g Mud Creek. (Control switches located on RTG3-102) .
NOTE: in the event barrier valves fail to open on signal, a tenporary air ju=per hose is available at barrier valve's air suppl /, and steps 5.5.1.1. - 5.5.'.4 nay be perferned to nanually open barrier 'r=!"es.
- 5. ' .1 Oparation Procadura 5.7.1.1 Allow nor=al novement in open direction *before attaching hose so upper piston void can
, intake air preventing a va.cuus frca forming.
. 5.7.t.2 Attach hose to upper pisten connection 5.7.1.3 Unlock and open supply air valve (3A 3 key) 5.7.1.4 Regulate 1-2 psig intervals until valve opens (Normally <5 psig opens valve) 5.3 Continue Reactor cooldown par 0F C030127.
6.0
References:
6.1 St. Lucie No. 1 FSAR, Section 9.2.7.
6.2 PSL Technical Specification Section 3.7.5.1.
6.3 Circulating ~4ater Systen Normal Operation, OP 0620020.
6.4 Turbine Shutdown, OP 0030125.
6.5 Reactor Cooldewn f ra Mode 3, OP 0030127.
7.0 Records Reeutred:
7.1 Normal log entries.
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"CCOMI:C RI'/:SION DIS"'l 3UT CN Sn.: :.T - 077 ?*C?lfAI. 5 O!IRCETC? CPIR. ?RCCEURI
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CCCUtiENT TITLZ Mdr#) n//
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DCC"0CC ?"I NUMBER 88/dd #d CCCOMEC RZ7:SICN NUM3E3 /3 CCCUMI:C DISTIC3CTID CU 2 m > E DATE DCC MZ2C SI:C 00:
COPY TRANS:CT"'AL COPY TRANSMIT"'A~.
NO. CCCOMENT ECLDER RETURNID NO. gCCCOMI:C ECLDER RE*'URNID
.6 CTCONTRCTf M CCPIES h
NEC-Regien C Actu: :".3PS 3P.ANCE usu.s f
- H. Paduano - GC
- 5 N. G. Roos A. 'J . 3411a'y 6 7* C G. =glahar: - C. r 7 7:nining 3 Trd"d- g 9 .*a:ch .:.sginaars ;., . Training g;. y 10 a.,+r~ w = m .~ ores C
,g. John Eoiven -Backf12 L u-u . .
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1.5 A .T". At.L - G. J. Boissy J. SPN.-4
. R. K Jennings H. M. Mercar RasM-- !"
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( m Acts: Chief, Nuciaar Responsa i-l I PRC C SID ST:' DATI ~! ~
*Moca: tiew distribution per instrue:1cus. F.ifac:1ve 9-L2-79. I
Page 1 of 12 FLORIDA ?O'4ER & LIG'd! COMPANY ST. LUCII UNIT $1 r EMERGENCY ?ROCEDURE 0810040 , REVISION 13
1.0 Title
MAIN STIAM LINE 3REAK
2.0 Acoroval
Reviewed by Plan N lear Safety Committee d'~dE/ Y 19 8 . Acoroved by - 3 a c_d Plant Manager 62J2pd# # # 19 74 . Revision 13 Reviewed by Facility Review Group d cd /3 19tf2. Approved E [ E /1.V> d Plant Manager ~~P - / ( - 19 k C7
3.0 Puroese
3.1 This procedure provides instructions to be followed in the event of an uncontrolled steam release from a steam generator. 3.2 Discuss'1ch:. .
. A rupture of a, steam line is assumed to include any accident which results in an uncontrolled steam rele'ase frei a steam generater. . The release can occur due to a break in a pipe line or from the nalfunction of atmospheric du=p valves or steam du=p and bypass valves or safety valves. The steam release results in an initial increase in steam flow which decreases during the accident as the steam pressure falls. The energy removal from the Reactor Coolant System causes a reduction of coolant temperature and pressure.
This transient results in the RCS being at saturation conditions with the potential. for void formations in the system. Operator actions should be directed toward establishing subcooled conditions in the Reactor Coolant System. 3.2.1 Core protection after a break would be provided by MSIS at 600 PSIA steam generator pressure and SIAS at 1600 PSIA pressurizer pressure or 5 PSIG containment pressure (break inside couremnant) . FOR INFORMATION ONLY This document is not controlled. Before use, verify information with 8 controlled document. i l l
- 4
1 Page 2 of 12 , EMERGENCY PROCEDURE 0810040, REV. L3 MAIN STEAM LINE BREAK j t .
3.0 Purpose
(Cont'd)
3.2. Discussion
(Cont'd) l w 3.2.2 All available indications should be used to aid in diagnosing the event since the accident may cause irregularities in a particular instrument reading. Critical parameters must be verified when one or more confirmatory indications are available. With the Subcooling Margin Monitor (9{M) operating normally, use the comograph on RTG3104 in conjunction with the SMM to eliminate dependence on a single instrument. With the 913 inoperable refer to the nomograph utilizing control room indicators such as TH0To pressurizer pressure and incore thermocouples to determine the margin to saturation. Subcooling margin can also be determined by subtracting hot leg temperature from pressurizer temperature (TE 1101).
4.0 Symotems
4.1 Continuously decreasing Tavg. 4.2 Abnormally low pressure in one or both steam generators. 4.3 Low pressurizer level.
. 4.4 Low pressurizer pressure.. .
4.5, High dentainment pressure (break insi'de containment) . 4.6 Initial rise in S.G. Level folicwed by rapid decrease in . affected steam generator leve'l. NOTE: Some instruments (valve position, temperature, pressure, level indication, etc.) specified for use in this procedure have not been designed for long teen post-steam line break conditions inside the containment. Therefore, the operator should be especially alert that the potential exists for erroneous indication after > 15 minutes have elapsed following a steam line break inside containment.
5.0 Instructions
5.1 Immediate Automatic Actions: 5.1.1 Reactor trip 5.1.2 Turbine trip 5.1.3 Generator lockout 5.1.4 Auxiliaries transfer to startup transformer 5.1.5 MSIS initiates at 600 psia SG press 5.1.6 Safety injection initiates at 1600 psia in pressurizer. 5.1.7 Containment isolation initiation from SIAS or at 5 psig containment pressure. 5.1.8 Containment spray initiates at 10 psig and SIAS. 3.1.9 Aux Feedwater Auto Start Sequence when either 5/G 1evel decreases to 34 indicated level. t 4
Pags 3 of 12 l 1 1 EMERGENCY PROCEDUPI 0810040, REV. ,13 MAIN STEAM LINE BREAK
5.0 Instructions
(cont) 5.2 Immediate Operator Action: 5.2.1 Carry out immediate operator actions for reactor trip per OP 0030130. 5.2.2 Af ter an SIAS caused by low reactor coolant system pressure and af ter it has been verified that all CEA's have been fully inserted for 5 seconds, stop all operating reactor coolant pumps. 5.2.3 Ensure MSIS initiated at 600 PSIA steam generator pressure or initiate manually. 5.2.4 Place both AFW auto start bypass switches in bypass to prevent feeding the faulted S/G. 5.2.5 Observe steam generator levels and pressures to determine affected steam generator. 5.2.6 Establish flow to the non-faulted steam generator when the cooldown transient has terninated and the RCS temperature is above 4000?. Maintain RCS temperature stable with steam dump to atmosphere on non-faulted steam generator. 5.3 Sub, sequent Action: , Observe all available indications to' determine conditions within . the RCS.. Use SMM display, RCS hot leg temperature, RCS cold , ! leg temperature, incore thermocouple temperature and RCS pressure to determine if the RCS is sub-cooled or saturated.
- An increase in temperature above the saturation temperature for the existing pressure is an indication of voiding in the RCS.
If this occurs the operator must ensure that the RCP's are turned ! off, the SIS is providing makeup to the RCS, and that the operable steam generator is removing heat from the RCS. 5.3.1 Refer to Table I to ensure the proper operation of engi-neered safety features as time and conditions permit. 5.3.2 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator". R13 l l l I
Pagz 4 of 12 EMERGENCY PROCEDURE 0810040, REV. 13 MAIN STEAM LINE BREAK
5.0 Instructions
(Cont'd) 5.3 Subsequent Action: (Cont'd) j ,,g 3.3.3 Check $'IAS to be initiated at 1600 psia pressurizer pressure or 5 psig containment pressure or initiate manually. Refer to Table I. 5.3.4 Check CIS initiation by SIAS or 5 psig containment pressure or initiate manually. Refer to Table I. 5.3.5 Check CSAS initiated at 10 psig containment pressure or initiate manually. Refer to Table I. 5.3.6 Maintain hot leg temperature less than 5200F with auxiliary feed and steam dump to atmosphere. NOTE: Do not admit auxiliary feed flow to the faulted steam generator regardless of location of break. 5.3.7 When pressurizer level on control channels indicates 30% energize all pressurizer heaters to aid in increasing RCS pressure. , 5.3.8 When pressurizer le' vel indicates 40% secure all charging. . pumps. 5.3.9 As hot leg temperature is maintained less than 520 F verify that pressurizer pressure stabilizes at approxi-mately 1250 psia (shut off head of EPSI). NOTE: Ensuring hot leg temperature less than 520 F and pressurizer pressure greater than 1250 psia ensures a margin of 50 F subcooled. 5.3.10 Stop emergency diesel generators if offsite power is available. 5.3.11 When coneminment pressure is less than 10 psig, reset CSAS. Stop containment spray pumps and close containment spray flow control valves FCV 07-1A and FCV 07-13. 5.3.12. When containment pressure is less than 5 psig, reset CIS. 5.3.13 Open MV 21-3 and MV 21-2 ICW to TCW heat exchangers. 5.3.14 Close HCV 14-3A and HCV 14-33, CCW outlet from SDC heat exchanger, to reduce CCW flow requirements. I'
l l Page 5 of 12 i i EMERGENCY PROCEDURE 0810041, REV. 13 , i MAIN STEAM LINE 3REAK 4
5.0 Instructions
(cont) i hume 5.3 Subsequent Action: (cont) 5.3.15 Restore CCW to the RCP's by performing the following steps: 5.3. 15 .1 Restore the non-essential CCW header: 5 . 3 . 15 . 1 . 1 Open 14-8A and HC7 14-9 ('N' header supply and return from 'A' CCW header). Open HCV 14-8B and HCV 14-10 ('N' header supply and return from 'B' CCW header). 5.3.15.2 Restore CCW flow to the RCP's as follows: 5.3.15.2.1 Open HC7 14-2 HCV 14-6 HCV 14-1 HC7 14-7 Reactor coolant pu=p CCW header
, . supply and return valves.
, 5.3.15.2.2 Open'the following valves to restore
. CCW flow to the individual RCP seal coolers.
HC7 14-il-1A1 HC7 14-11-1A2 HC7 14-11-1B1 HCV 14-11-132 Note: It may be necessary to cycle these valves to restore flow. , 5.3.16 To allow potential ECCS area radioactive leakage and RCS sample water, collected in the ECCS area sumos to be pumped to the Reactor Coolant Drain Tank inside containment, perform the following:
- 1. At the C.R.A.C. panel place the "ECCS Area Leakage System" control switch to the "RDT" position and ensure that: ;
HCV-06-9 "R.D. Pump Suction" closes HC7-06-7 " Sump Pump to EDT" closes HCV-06-8 " Sump Pump to RDT" opens l I
Page 6 of 12 EMERGENCY PROCEDURE 0810041, REV. 13 MAIN STEAM LINE 3REAK
5.0 Instructions
(cont) 5.3 Subsequent Action: (cont) 5.3.16 (cont) l
- 2. At RTGB 105 open A0V-6301 and A0V-6302 "RDT Centmc Isol" valves by placing the switches in reset, then open positions.
- 3. Ensure the C.R.A.C. panel annunciator "ECCS Pump Roon )
Leakage Valves Miraligned" is not lit, j l NOTE: The following valves are provided with "CIS-0VERRIDE" l capability: A0V-5200, 5203 " Reactor Coolan: Sample" FCV-26-1, 3 " Containment Sample Supply" FCV-26-2,4 " Containment Sample Return" A0V-6301, 6302 "RDT Containtenc Isolation" 5.3.17 Re-establish charging and letdown per OP #0210030 charging and letddwn off-normal operation. . 5.3.18 ,When HPSI pumps have run for at least 20 einutes and 50 F , sub-cooling is established, the pumps may be secured.
- 5.3.19 Continue a controlled cooldewn in accordance with OP #0030127.
NOTE: Portions of the containment sprav system will contain Na0H. 5.3.19 Notify Duty Call Supervisor. t
, I d
Paga 7 of 12 x s I EMERGENCY PROCEDURE NO. 0810040, REV. 13 N MAIN STEAM LINE 3REAK )
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6.0 References. 6.1 FSAR, Sections 6, 7, and 15. ' s-, s 4 7.0 Records Required: . .g , s , 7,1 Normal Log Entry ' - s 7.2 "AP0010134 ' Component Cycles and Transients."
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, EMERGENCY PROCEDURE NO. 0810040, REV 13 Page 8 of 12 MAIN STEAM LINE BREAK
, ;*\ TABLE I f
( 1.0 Safety Iniection Actuation Signal I , 1.1 Two HPSI Pumps ON l.2 Two LPSI Pumns ON 1.3 Eight RPSI Discharge Valves (HCV-3e17, 3627, 3637, 3647% OPEN
[(' ed.
~4 1.4 Four LPSI Discharge Valves (HCV-3615, 3625, 3635, 3645) OPEN s . 1.5 Check proper operation of the Safety Injection System by the following means.
1.5.1 Check HPSI flow rates on: FI-3311, 3321, - u 3331, 3341.
;l 1.5.2 Check LPSI flow rates on: FI-3312, 3322, 3332, 3342.
1.5.3 Check decreasing Safety Injection Tank Levels on: LIA-3311, 3321, 3331, 3341. 1.6 Two CCW Pumps ON 1.7 Two CCW Valves from SDC HX's (HCV 14-3A, HCV 14-3B). OPEN t ' l.3 Four Containment Cooline Fans ON s( 1- 1.9 Tlour CCW "N-Header" Isolation Valves (HCV-14-6A, 14-9, 14-83, 14-10). SHUT 1.10 Four S!! Check Valve Leakoff Valves (V-3618, . 1 3628. 363S. 3648). SHUT 1.11 Two R.A.3. Main Sucoly Fans (HVS-4A, 45) ON 1.12 Two EGC5 Area Exhaust Fans (HVE 9A, 93) ON*
}* 1.13 Eight Aux Bldg Dampers (D-5A, 6A, 9A, LZA, 53, 63, 9B. 12B) SHUT -
L.14 Four Aux Bldg /ECCS Pu=p Room Dampers -(D-13,14, 15, 16) OPEN 1.15 Four Reactor Coolant Pump CCW Isolation Vaives (HCV-14-1, 14-2, 14-6, 14-7). 5 HUT 1.16 Two FWP Discharge Valves (MV-09-1; MV-09-2) SHUT l.17 Two Feedwater Block Valves (MV-09-7; MV-09-8) SHUT
, 1.18 Two Charging Pumos ON 1.19 Two Boric Acid Makeup Pumps. ON 1.20 Two Letdown Isolation valves (V-2515; V-2516) SHUT 1.21 VCT outlet Valve (V-2501) SHUT 1.22 Two Gravity Feed Valves (V-2508: V-2509) OPEN 1.23 Emergency Borate Valve (MV-2514) OPEN 1.24 Two Bam Pumo Recire Valves (V-2510, V-2511) SHUT _
l.25 Elender Outlet valve to VCT (V-2512) SHUT 1.26 Load Control Valve (MV-2525) SHUT i 1.27 Boric Acid Header Discharge Valve (MV-2161) SHUT 1.28 Two Rx Cavity Sump Isol Valves (LCV 07-11A; LCV 07-IIB) SHUT l.29 Two Intake Cooling Water Pumps ON 1 1.30 Two ICW to TCW Rx Isol Valves (MV-21-2: MV-21-3) SHUT 1.31 ' A'ICW Lube Water Supply _to CW Pumos (ECV 21-3A) SHUT R/11 1.32 'B'ICW Lube Water _Supolv to CW Pumo (Fcv 21-1g3 SHUT = R/11 NN
- NOTE: Only one ECCS arca exh' a ust fan is required, the other fan "p' .
should be shutdown and kept in standby. l l
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Page 9 of 12 EMERGENCY PROCEDURE No. 0810040, REV 13 ~
. MAIN STEAM LINE 3REAK r
==
TABLE 1 2.0 Containment Is'olation Actuation Signal 2.1 Two Shield Building Vent Fans (HVE-6A, HVE-6B) ON*
. 2.2 Two Control Room Vent Booster Fans (HV E-13A , HVE-13B) ON
**a. 2.3 Two Letdown Isolation Valves (V-2516, V2515) SHUT 2.4 Two RCS Samole Isolation Valves (V-5200, V-5203) SHUT 2.5 Four Pressurizer Sample Valves (V-5201, V-5202, V-5204, V-5205) SHU-2.6 One Instrument Air To Containment Isolation Valve (MV-18-1) SHUT
**b . 2.7 Six Containment Purge Valves (FCV-25-1, 25-3, 25-5, 25-6, 25-4, 25-2) SHU~
2.8 Two Containment Purt;e E::haust Fans (TIE-8A. EVE-83) 0FF 2.9 One Nitrogen to Contairent Sucolv Valve (V-674!T SHTIT 2.10 Two Containment Waste Gas P.eader Isolation Valves (V-6554, V-6555) SHUT 2.11 Two Containment Sump Pump Discharge Valves (LCV-07-llA, LCV-07-113) SHUT 2.12 Four Steam Generator Blowdown Isolation Valves (FCV-23-3, FCV-23-5. FCV-23-4, FCV-23-6) SHUT - 2.13 Two Steam Generator BIowdown. Sample Isolation Valvas (FCV' 23-7 and 9) SHUT 2.14 Two Reactor Drain Tank Discharge Isolation Valves (V-6301, V-6302) SHUT 2.15 Four Control Room Air Inlet Valves (FCV-25-16, FCV-25-17, FCV-25-14, FCV-25-15) SHUT 2.16 Two Control Room Kitchen Air Exhaust Valves (FCV-25-24, FCV-25-25) cum 2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18, FCV-25-19) SHUT
**c. 2.18 Six ContMnment Radiation Sample Suction and Return Valves (FCV-26-2. 4, 6 FCV-26-1. 3, 5) SHUT 2.19 Primary Makeup Water Isol Valve (MV-15-1) SHUT 2.20 Two RCP Controlled Bleedorf Isol Valves (V-2505 and ISE-01-1) SHUT
- NOTE: Only one shield building vent fan is required, the other should be shutdown and kept in standby.
** N Due to the possibility of NAMCO position indication switch failure on the letdown isolation valves, V2515, V-2516, containment purge valves FCV25-3, FCV25-4, and radiation monitor isolation valves FCV26-1, FCV26-3, FCV26-3, perform the following on receipt of valid CIS.
- a. V2515, V2516: Close valves using switch on RTGB, ensure valves closed by observing letdown flow, press
- b. FCV25-3, FCV25-4: Ensure other valves in the line are closed (FCV25-1, FCV25-2, FCv25-5, FCV25-6).
- c. FCV26-1, FCV26-3, FCV26-5: Close valves using RTGB switch, close
! manual valves at monitor cabinet, ensure no flow indication on monitor. I 4 g i A
Paga 10 of 12 EMERGENCY PROCEDURE NO. 0810040, REV _l3 MAIN STEAM LEE 3REAK mama TABLE 1 3.0 Containment Sorav Actuation Signal 3.1 Two Containment Spray Pumos ON
- 3. 2 Two Containment Spray Header Inlet Valves (FCV-07-1A, FCV-07-1B) OPC4 3.3 Four NACH (Caustic) Admission Valves (FSE-07-1A, FSE-07-2A. FSE-07-1B, FSE-07-2B) 0 FEN 3.4 Verify Containment Spray Flow in FI-07-1A and FI-07-1B.
3.5 Verify NA0H (Caustic). Flow on Post Accident Panel "A" (FI-07-2, FR-07-2)
- 4 '
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i l Page 11 of 12 DIERGENCY PROCEDURE NO. 0810040, REV 13 MAIN STEAM LDIE BREAK l l l i. TABLE 1 4.0 Recirculation Actuation Signal Two LPSI Pumpc OFF 4.1 4.2 Two Safety Injection Miniflow Recire. Valves (V-3659, SHUT V-3660) OPEN 4.3 Two Containment Sumo outlet Valves (MV-07-2A. MV-07-2B) Tuo RWr Outlet Valves (MV-0 7-1A , MV-0 7-13) SHUT 4.4 4.5 Verify HPSI ficw to core continues af ter RAS on FI-3321, FI-3341, FI-3311, FI-3331.
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Page 12 of 12 f EMERGENCY PROCEDURE NO. 0810040, REV 13- l MAri STEAM LDE. BREAK TABLE I i i 5.0 Main Steam Isolation Signal SHUT dW 5.1 Two Main Steam Isolation Valves (HCV-08-LA. HCV-08-1B) 5.2 Two Main Steam Isolation Bypass Valves (MV-08-1A, SHUT MV-08-13) 5.3 Two Main Feedwater Pump Discharge Valves (MV-09-1, SHUT MV-09-2) Two Main Feedwater Block Valves (MV-09-7, MV-09-8) SHUT 5.4
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l t f Page 1 of li ILORD A ?CkT.R & LIGHT CCMPANY ST. LUCIE UNIT 11 OfERGENCY OPERATING ?RCCEDURE NO. 0030140 RE7ISICN 24 s ; 1 i
1.0 Title
70 Q l37$$M7,IC] G y {,'/-- ]i q [ MxYnUT OPERATION This document is not controlled. Before use, verify information with a confroHed document. 2.0 .\p o roval: Reviewed by ? uclear Safety Committee MW /f' 1979 Approved by. . /hA > Plant Manager #M,)/A pf
,. 19 "%
Revision 24 Reviewed b'y Fac111cv Review Group MS cd /7
~ 19 e d Anproved h MA#. /Z/M Plant .Vanaaer T- - /.4 ~ - 19 J:
3.0 Pureose or Discussion: 3.1 This procedure provides the action to be taken in the event of a complete less of off site electrical power concurrent with a turbine trip. 3.2 Discussion 3.2.1' A less of power to the 4160 V buses, results in a loss of power to all 480.7 load centers and noter control centers and to all instrumentation not fed dire,ctly or* indirectly * -
. - , from the station battery. A resce,or trip vill occur from a low reactor coolant flow race signal due to the loss of power to the 6900 7 buses supplying the reactor coolant pumps and will be accompanied by a turbine trip and generator lockout.
3.2.2 Steam dump to atmosphere :nst be used to remove reactor decay heat. Initially, steam generator safety valves nay actuate to sugnent the steam flew and to-help Ocutrol stame generator pressure i= mediately after the trip. 3.2.3 on site power will be supplied by Emergency Generators. 3.3 A rapid reduction in steam generator wecer levels will occur due to the reduction of the steam generator void fraction on the secondary side and also because steam flow 411 continue after normal feedwater flow stops. Auxiliary feedwater flow ~ l1.u. auteniacTcaWiiiiciate 3 el:iistes af ter tW.first steam generator lever reaches ~34" (2/4 logic 7. 3.4 Core decay heat removal is accomplished by natural circulation in the reactor coolant loops. 3.5 Core damage is not expected as a result of a loss of power I condition as the steam generators are maintained as a heat sink and no loss of water occurs from the pressurizar. l
Page 2 of 14 EMERGENCY OPERACNG PROCEDURE NO. 0030140, REV 24 3LACIOUT OPERAHCN I 3.0 ?ureose or Discussion: (cene) 4 i 3.6 If operacing under blackout condi: ions and an engineered safety features actuacion signal occurs, any non emergency 8 loads -dac are :-mning will be automatically chpped and
- he required emergency loads will be automatically started.
4.0 Svapcoas
4.1 Alarms associated with the loss of operating plane components. 4.2 Loss of normal control room lighting and DC lighting energized. 4.3 Reactor and turbine trip. 4.4 Emergency diesel generacers start. 4.5 Reactor coolant pump trip and steam generator feed pump trip. 4 e e g e b 1 l l
l l Page 3 of 14 IMERGUCT OPERAIDG PRCCEDURE NO. 0030140, REV 24 3LACKCU"' OPERAT!CN p
5.0 Instructions
)
e 1 5.1 Immediate auto action .1 l 5.1.L Reactor and turbine trip, generator lockout 5.1.2 Generator breakers open. 5.1.3 Incoming feeder breakers open to 4160 V and 6900 V buses. 5.1.4 Tie breakers between Nornal 4160 buses (IA2 and 132) and the emergency 4160 V buses (IA3 and 133) open. 5.1.5 Ties between essential and non-essencial sections of emergency 480 V MCC's open. 5.1.6 3reakers open for the following non-safety related loads which are nor= ally fed from e=ergency buses. NOTE: These loads can be -m rally reconnected to tha emergency buses as needed. 5.1.6.1 Pressurizer heater transformers lA and 13. *
. 5.1.6.2 Fire pump 1A.and 13. .
, 5..l.6.3 CIA Drive M.G. LA & 13. .
- 5.1.6.4 Fuel h ndling 480 V )iCC 1A8, 138/
- 5.1.6.5 Reactor cavity sump pump 1A *
- 5.1.6.6 Reactor building elevator 5.1.6.7 Electrical equipment room hoist 5.1.6.8 L20/208 power panel 121 transformer 5.1.6.9 Lighting panel transformers 110, 112, 114, 117, 125, 126 5.1.6.10 Incoming feeder from 1A2 & 132 4160V buses 5.1.6.11 RC? oil lif e pumps (3 pumps only - A pumps :T.nning) 5.1.6.11 Airborne radioactivity removal fans EVE-l&2 5.1.6.13 Pressurizar relief isol valves 1403 & 1405 /R22 5.1.6.14 CVCS heat tracing transformer 1A & 13 5.1.6.15 4807 Lighting panel 2A, 23 & 2C 5.1.6.16 Waste nanagement heat tracing transformers 2A & 23 5.1.6.17 Air conditioner EVA-4, ACC-4.
5.1.6.13 Power panel 120 5.1.6.19 Lighting panels 113, 116, 109, 115, 130 5.1.6.20 Refueling equipment 5.1.6.21 Refueling water to charging pumps V-2504 5.1.6.22 Boric Acid bacching tank heaters 3.1 6.23 Fir _e siren
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i l l Page 4 of 14 DfERGENCY OPERATING PROCEDURE NO. 0030140, RE7 24 3LACIOUT OPERATION
5.0 Instructions
(cont) I .,
? l 5.1 (cont) ; I 5.1.7 All loads on emergency buses are tripped except f the following: 6 5.1.7.1 Boric Acid makeup pumps 5.1.7.2 Charging pumps 5.1.7.3 Emergency lighting 5.1.7.4 Class I power panels 5.1.7.5 RCP oil lift pumps (A pumps only - 3 pumps off) 5.1.7.6 Diesel fuel transfer pump.
5.1.8 Diesel generators A & B start and energize 4160 V emergency buses lA3,133, and 1AB and 1 cads listed in step 5.L.7. 5.1.9 Subsequent loads are startad at 3 second intervals. See Tabla 1, Emergency Diesel Canerator Leading Sequence. 3.1.10 Aiivn fary Feedwater auto star: sequence initiates when the first steam generator level decreases to 34%. NOTE: Pump start and flow iniciation'is delayed for 3 minutes. ' Pumps nay be started by the operator AT ANY TDfE. 5.2 Immediate Operator Actions
- 5.2.1 Trip turbine and reactor manually.
5.2.2 Check all full length CEA's are fully inserted and reactor trip breakers are open. 5.2.3 Check turbine valves are closed. 5.2.4 Check generator field and 240 K7 breakers are open. 5.2.5 Place reheater control system in manual, close TC7's. 5.2.6 Check that diesel generators have started and are feeding only emergency buses. 5.2.7 open :, cart-up transformer breakers. ' I 5.2.8 Reduce Tayg to reference set point by manual operation of the steam dump valves to atmosphere. 5.2.9 Isolate steam generator blowdown. ll 1
Psge 5 of 14
?
cL"lGENCY OPERATING PROCEDURE NO. 0030140, REY. 24 31ACKCUT OPERATION i j !
5.0 Instruccion
(Cont'd) . i j 8 5.2 I::nnediate Operation Action (Cone ' d) jw-5.2.10 start steam driven aux. feed pump and establish flow to S.G.'s. If aux. feed pumps have started due to the auto start feature, the notor driven pumps nay be secured 30 seconds af ter eney start, if desired.
~ a.z.IFIf stfy of tKa autoinatic accrodh IisEd fn K2.2 thru "l
~ ~5 2.y co KorWcutnlutomhtically, then shhually"inftface that action.
5.2.12 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, "Outies of the E=ergency Coordinator". /R24 5.3 Subsequent Action 5.3.1 Ensure adequate natural circulation flow by ensuring that hot and cold leg temperatures, pressurizer e pressure and level stabilize within nicutes. The , core AT.should be less chan ,s 44 F (AT for full power). 5.3.1.1 If the above conditions are not established:
- 5. 3.1.1.1 Check RCS temperature and pressure to ensure that the RCS is subcooled.
5.3.1.1.2 Insure auxiliary feed flow to the steam generators has been initiated and the steam dumps to atmosphere are in operation. 5.3.1.2 Return at least one RCP in each loop to operation as soon as offsite power is available 5.3.2 Start equipment.in Table 1 if required. i i
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Pags 6 of 14 EfERCINCY OPERATING ?RCCO URE NO. 0030140, ! REVISION 24 3LACKOUT OPERATION g
5.0 Instruction
(Cont'd) l 5.3 (cont'd) ) 5.3.3 If one diesel fails to start, atte=pt a =anual start. 5.3.3.1 If manual start attempt is unsuccessful, an operator should be sent to the diesel local control station to inspect status of local alarm panel. 5.3.3.2 If no alarms are present on the local alarm panel, an inspection of the overspeed trip lever should be made to insure it has not tripped. 5.3.3.3 If the overspeed trip levers are latched, the nor=al isolate switches on the local control panel should be placed in the isolate position and a local start attempt should be made. 5.3.3.4 Refer to Operating Procedure 2200020, 2200050 Emergency Diesel Stancoy Line up and Periodic Test. 5.3.4. iacally open condenser vacuum breakers MN10-1A and *
. NV10-13. Locally close MSR sain steam block valv,es MV08-4, MV08-6, MV08-8, and MV08-10. ,
5.3.5 Check MSR warm-up valves MV08-5, MV08-7, MV-9, and M708-11 to be closed or close =anually. 5.3.6 Send an operator to align and start emergency cooling water to the instrument air compressor, then reset local handswitch and manually start the instrument air compressor. CAUTION: Do not overload the diesel generators when starring additional equipment. (3500 r4 max. continuous racing). 5.3.7 When diesel generator power is available energize equipment as may be required for plant safety and to achieve an orderly shutdown within the diesel gener-ator load limitations by: 5.3.7.1 verify one set of cavity and support cooling fans operating. If not, start one sec. 5.3.7.2 Locking out automatic starting equipment that is not in service. 5.3.7.3 Mantially opening all . breakers on any non-vital bus or =ocer control center that is to be re-energited. l
Page 7 of 14 IMERGENCT OPERATING PROCEDURE NO. 0030140, REVISION 24 3 LACK 0UT OPERA ~ ION j L== !
5.0 Instructions
(Cont) { $ 5 5.3 (Cont) " i h. 5.3.7 (Cont) ' 5 5.3.7.4 Resetting lockout relays for each required U bus to anow closing of feeder breakers. 5.3.3 Energize 4160 7 buses lA2, 132, 480 V load centers lA1, - 131 and 480 MCC's IA1,131, lA4,134, and 1C as fonows: ACTION LOCATION 5.3.3.1 Strip non-vital 4.16 KV busses lAl 132 (All should be opened automatically) 5.3.8.2 Insert sync plug, close 4.16 K7 1A2-20109 132-20309 non-vital breaker and hold control switch closed while closing 4.16 K7 vital breaker. 1A3-20209 133-20411
- 5. 3.8 . 3 Strip con-vital lead cantar 1Al 131
- 5. 3.3 . 4 Close 4.16KV feed breaker to non-vital lead centers lA2-20110 132-20310
, 5.38.5 Strip 480V MCC .
1A1 131-
. . -lA4 .
134 5g 5.3.3.6 Close 480V lead center feed breaker to MCC 1A1 & 131 1Al-40115 131-40411 5.3.8.7 Close 4807 load center feed breaker to MCC 1A4 & 134 1Al-40113 131-40413 5.3.3.8 Close 480V load cantar feed breaker to MCC 1C 1Al-40H9 131-40410 5.3.9 At MCC 1C, close breakers for turning gear, bearing oil pump, air side seal oil pump and hydrogen seal oil pump. 5.3.10 Place turbine plant coollag water pump in operation. 5.3.n Align turbine cooling water system to the instrument air compressor back to nornal alignment. 5.3.n.1 Open au Ck 's on PP-104 except Ck 's 21 & 23. 3.3. n.2 Close 3reaker 40851 on MCC 1A1 5.3.u.3 open au Ck:'s on PP-146 except Ck: 1. t
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Page 3 of 14 l l DERGENCY OPERAUNG PROCEDURE NO. 0030140, REVISION 24 3LACKCUT OPERATION [o f;
5.0 Instructions
(Cent) 2 i
@ i I 5.3.11.3.1 Open all Ckt's on ??-150 l !
except Cke's 7,9 and 11. NOTE: PP-146 is located on the wall of the new cold lab just vest of MCC 131. PP-150 is located in the new cold lab closet. 5.3.11.4 Close 3reaker 41634 on MCC 131. 5.3.12 Place turbine drain valve switch in the open position. 5.3.13 Star: bearing oil pump before curbing bearing oil pressure reaches 12 psig. decreasing. Pump starts automatically at 12 psig decreasing turbine bearing oil pressure. NOTE: If' bearing oil pu=p fails to start, the emergency DC oil pu=p vill start at 10 psig decreasing bearing oil pressure. Operator should start pump before 10 psig is reached. Stop the DC cil pu=p if it is runMng in addition to the bearing oil pump. 5*.3'.14 Remove the following components from service: 5.3.14.1* Steam'j et air ej ectors 5.3.14.2 Priming ejector 5.3.14.3 Anv414 mry priming ejector 5.3.14.4 Auxiliary steam to R.A.3. 5.3.14.5 Gland seal system 5.3.15 5 tar: CEDM cooling fans A & 3. 5.3.16. Start reactor support cooling fans A & 3. CAUTION: Consider equipment serrting requirements. Alternate operation of equipment may be required to avoid overloading the. diesel
- generators. (3500 KW Max. continuous rating).
5.3.17 .w=an=117 close breakers for pressurizer heater buses on 4150 V buses IA3 and 133. l I t
Page 9 of 14 EMERGINCY OPERATING ?ROCEDURE NO. 0030140, REV 24 3 LACK 0UT OPERATION o 3 5.0 Inst uctions: (cent) ia ) 1 - 5.3 (cont) 1 ( 5.3.18 Check that the bearing oil lift pump starts automatically when turbine speed decreases to approximately 600 rpm. 5.3.19 Starr turbine lube oil vapor extractor and generator oil vapor extractor. 5.3.20 Check that the turning gear engages and starts auto-matically when turbine speed decreases to tero rpm, or manually engage it. 5.3.21 Reduce the flow of cooling water to maintain the temperature of the oil leaving the turbine lube oil and the air side and hydrogen side oil coolers be-tween 95 - 100 7. 5.3.22 Isolate cooling water supply to the generator hydrogen coolers. 5.3.23. If additional condensate storage tank water is
. required and sufficient power is available from the diesel generators, place the water treatment plant '
in service. . 5.3.24 Place the spent fuel pic cooling pump in operation as necessary. NOTE: With spent fuel elements from 3-l/3 cores present, the spent fuel pit can safely wichstand 5 hours without cooling before reaching the boiling point. 5.3.25 Periodically check fuel oil levels in the diesti generator day tanks to confirm proper operation of the fuel oil transfer system and to ensure uninter-rupted diesel generator operation. 5.3.26 Sample and analy:e the reactor coolant to deter =ine if fuel element clad failure has occurred. 5.3.27 Determine expected duration of power outage. If unable to do so or if outage is to be prolonged, borate RCS to cold shutdown concentration. 5.3.28 If the outage will exceed 4 hours and the RWT is available, proceed to cold shutdown conditions utilizing thermal circulation, atmospheric steam dump and feedwater addition. Place shutdown cooling in service when appropriate temperatures and pressures are reached. Proceed to step 5.3.32. l 1
1 Page 10 of 14 IMERGENCY OPERA 2iG ?ROCEDURE :fo. 0030140, RE7 26 SLACK 0UT OPERATION i i
5.0 Instructicos
(cont) , j 5.3 (cont) l ! 5.3.28 (cont) { in m NOTE: Do not begin plant cooldown until cold shutdown boron concentration is verified. 5.3. 29 If the outage will uceed 4 hours and the RWT is not available, the Safety Injection tanks should be used for makeup to the RCS, if other sources are not available. 5.3.30 Make the following preparaticas:
- 5. 3. 3.0.1 Close either or both non-essential tie breakers for MCC 1A5 and MCC 135 1A5 - 41230 135 - 42027 This will provide power to the containment instrument air conpressors.
5.3.30.2 If running of centainment instrument air
, compressors is not desirable,, insure that , . . a turbine building instrument air compressor.
is running and containment instrument air,
. pressure is normal.
5.3.30.3 open the 480 V AC breakers for Mov-2501 and W V-2504 MOV-250L - 42021 M07-2504 - 42017 5.3.30.4 Open and lock the following valves: 7-07009 SIT tasa line return to RWT penetratica 941 . 7-3443 SIT test line return to RWT penetration $41 7-03920 SIT test line tie to 7CT inlac l 5.3.30.5 Borate he RCS to cold shutdown boron concentration. t CAUTION: Insure that one 3AMI cank ramains in service to use as a source of
. borated water while in mode 5. .
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Page 11 of 14 DERGE. .~ JPERAI!NG PROCEDURE NO. 0030140, REV 24 , 3LACKOUT OPERATION l 5.0 Ins tructions : (cont) y , A 5.3 (cont) ! il : 5.3.31 Proceed to cold shutdown conditions utilizing thermal circulation, atmospheric steam dump and feedwater addition. 5.3.31.1 '4 hen makeup to VC is necessary, select a S. I.T. to use as makeup source. Open the appropriate tanks, fill and drain valve. lAl - A0V-3621 1A2 - A0V-3611 131 - A0V-3631 132 - A0V-3641 5.3.31.2 Close the appropriate fill and drain valve when VCT is restored to normal level. CAUTION: Use one SIT tank at a time. Insure RCS is 1750 psia before the second SI: cank is used. 5.3.'31.3 Place shutdown cooling in service when .
, appr'opriate temperatures .and pressures are reached. .
5.3.32 If pressurizer *ccoldown cannot be accomplished in a timely manner from the addition of cooler liquid (Aux. Spray) from the charging pump via the pressurizar spray line, proceed with the alternate positive means of depressurization as follows: 5.3.32.1 Place the switches for the power operated relief valves V1402 and V1404 in the override position. 5.3.32.2 Initiate a high pressur12er pressure trip signal on two RPS channel trip units. 5.3.32.3 Place the switch for either power operated relief valve (71402 or 71404) in the normal range position and vent the pressurizer to the quench tank. Return the switch to override to close valve. 5.3.32.4 Control the rata of cooldown and depressurization , by selective operation of the power operacad
- relief valves in this node until cooldown via the Ane l bry Spray valves can be initiated.
l < 1
l Page 12 of 14 EMERGETCT OPERATCTG PROCEDURE NO. 0030140, REV 24 3 LACK 0UT OPERATION i 5.0 Instrue:1ons: (cone) 1 i4 ! 5.3 (cont) 1
=
5.3.33 When normal AC power is available: f i 5.3.33.1 Restore bus sections :o their normal supplies. 5.3.33.2 Place the diesel generator system is standby lineup as per OP 2200020. 5.3.33.3 Restors all plant systems to normal. .
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? age 13 of 14 EMERGENCY OPERATING PRCCEDURE NO. 0030140, REV 24 ,
3tACKCUT OPERATION [
.i 0 4 6.0
References:
I ! 6.1 FSAR, Section 15 il a
-n n,
6.2 PSAR, Section 8 lfyg 6.3 Operating Procedure #0030130, Shutdown Resulting From Reactor / Turbine Trip 6.4 Operating Procedure #0210020, Charging and Letdown 6.5 Operating Procedure #0330020, Turbine Cooling Water Operation 6.6 Operating Procedure #0250031, 3oren concentration control, Off-Normal 6.7 Operating Procedure #1010040, Loss of hstrument Air 6.8 Operating Procedure #1540020, 'Jacer Plant Startup and Shutdown 6.9 Operating Procedure #2000020, Inergency Diasals - Standby Lineup 6.10 Operating Procedure 107C0022, A::.m. Feedwatar Systam Operation
7.0 RecordsVNotification
7.1 Normal Log Enpries, 7.2 Notify Duty Call Supervisor. 7.3 AP 0010134 " Component Cycles and Transients" R/23 I l l I
0030140 TAP.LE I _ _ _ _ _ _ ___jl * "** .#4 E4 oF F4 EHERCENCY 11EESEL CENERATOR LOAlllNG SEQUENCE Loss of Coolant Accident Loss of and Loss of off-Site Pouer off-Site Power Nomina l Running TimingA Running S e rvic e Qty Load - Ea Load - Ku Starting Running Load - Ku HPSI pump 400 llP 330 From Boric acid makeup pump 1 1 25 lie 22' From 0.2 Sec - Cont 0 Sec - 4 lirs 1st 22 {8-Charging pump 1 100 tiP 80 From 0 Sec - 4 lirs Block 80 Hotor opera ted valves Lot 60 IIP 40 From 0 Sec - 1 min - Emergency lighting Lot 50 KW 50 From 0 Sec - Cont 50 Class I power panels 4 45KVA ,40 From 0 Sec - Cont 40 4 Fuel Transfer Puup L 5 tir 5 From 0 Sec - Cont 5 1 PSI pwap 1 400 llP 330 From 3 Sec - 90 min 2nd 310 containmnet f an coolers 2 150 llP 245 From 3 Sec - Cont Block 167 Component coolant pump 1 450 ItP - 376 From 6 Sec - Cont 376 Sliteld bid vent fan 1 60 IIP $4 From 6 Sec - Cont 3rd - Shield Bld Vent Sys Elec litr 1 30Kil ,30 From 6 Sec - Coat Block - D-C Bld Ekla. Fan I lilP 1 From 6 Sec - Cont I g Intake cooling pump 1 600 llP 492 From 9 Sec - Cont 4tli Block 492 Containment spray pump 1 500 llP 400 From 12 Sec - Cont 5th Block - Auxiliary feedwater pump 1 350 IIP 305 From 15 Sec - 4 hrs 6Lli Block 305 Boric acid heating I Lot SI .75 KW 51.75 From 18 Sec - 4 hrs 51.75 Auxiliary bid supply fan 1 60 llP 54 From 18 Sec - Cont 54 ECCS Area ekhaust system 1 50 IIP 44 From 18 Sec - Cont 7 tli 44 Cont rol Room AC Outdoor linit 1 50 llP 44
- From 18 Sec - Cont Block 44 Control room AC Indoor Unit 1 7 .5 lip 8* From 18 Sec - Cont 8 '
control room booster fan 1 3 llP 3 From 18 Sec - Cont 3 Heactor Support Cl4 Fan 1 40 IIP 37 From 18 Sec - Cont 37 Heactor Cavity CLG Fan 1 20 IIP
- 19 From 18 Sec - Cont 19 Bat tery Cliarger 1 68 KVA 68 From 30 Soc - Cont 8th 68 Plant Security Inverter 1 20 KVA 20 From 30 Sec - Cont Block 20 UPS Inverter 1 15 KVA 15 From 30 Sec - Cont !$
Fire Pump i 250 Ilf ** From 35 Sec - ** Totals: 3163.75 ku__ 2429.{}8 kw (maximum, 18 Sec - 30 min) A Counting (rua the time the D-C bredkcr Closes,
** Auto-start feature on itre pump is defeated if SIAS fu present.
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Page 1 of 23 F10RIDA POWER 5 LIGHT COMPANY ST. LUC!I 17!! 11 EMERGENCY CPERATING PROCEDURE 0030141 j Rzvts!ON 9 , ; L i I' i 1
" 0 ,"'
Control Room Inaccessibill:y FOR IMF0m.1AT!0H OHLY w This docirment ..< cot controlled. Before use,
2.0 Amoroval
verify info mHen wich a controlled document. Reviewed by ?1 ,Nyclea.rSafetyCommic:ee 1 2., Approved by '41/rviA M 19 7.f'" Plant Manager .u, ,o.s /? F 19E Revision 9 Reviewed by Facili:y Review Group ##a e .d /1 19E 1 Approved 57 d.#44/>K - Plant Manager 7 .- / 4, 19 g 3.0 Purcose & Discussion: 3.1 *he purpose of this procedure is :o provide instru::i:ns f:r placing the plant in a safe condi:1on when operations cannot safaly be conducted from che control room. 3.2 The reactor and turbine are nanually tripped prior to leaving the control room if possible or locally from the Reac:dr Trip Switch-gear and the turbine front standard. ,'
- 3.3 A heat sink is provided by automatic steam dump to :he condenser c,
and/or to ' atmosphere. - 3.4 level is naistained in the steam generators by nanual control of auxiliary feedvacer valves with flow furnished by :he auxiliary feedwater punps. 3.5 Pressurizer level and pressure are naiscained by nanual :entrol of ;rassurizar heaters, spray valves and letdown valves and ara nonitored at the hoc shutdown panel. 3.6 Isolation switches located in the Reactor Auxiliary Building Electrical Equipment Room, the Turbine Building Svi chgear Room, :he Diesel Generator Rooms, and the Reactor Auxiliary Building are nanually I selected to the isolace posi:1on :o prevent inadvertent operacion of vi:al equipment due to possible elec:rical nalfunc:1on in :he unac: ended control room.
- 3. 7 A copy of this procedure will be posted at each nanned operating station required for planc shutdown from outside the control center.
3.8 A listing of 1sclacion' switches will be pesced on each of the following panels, MCC's and distribution buses. l a) Load Cancers LA, 13, lAS I b) Isolation Sw1:ch Panels A, 3, LAB c) MCC 1AS, lA6, 135, 136 d) 41607 3uses LA3,133, LAB e) 4160V Suses LA2, 132 f) 69007 Buses LA1, 131 g
- 7) Diesel Generacor A & 3 Control Panels .
Page 2 of 28 EMERGENCY OPERATING PROCEDURE 0030141 REVISION 9 3.0 Purpose & Discussion: (con't.) . 3.9 The Plant Supervisor will utilize additional personnel as available to assist in required subsequent actions.
4.0 Symptoms
4.1 Conditions existing such that the Control Room becomes uninhabitable and must be evacuated.
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Page 3 of 28 t EMERGENCY OPERATING PROCEDURE 0030141 ! REVISION 9 l
5.0 Instructions
l 5.1 Immediate Action 1 5.1.1 ManualF trip the Reactor and Turbine before leaving the i Controi toom, if possible 8 === 5.1.2 Announce evacuation of the Control Room over the P.A. System, 5.1.3 Implement the Emergency Plan as necessary in accordance with , EPIP 310021E, " Duties of the Emergency Coordinator". R9 5.1.4 Man and take control of emergency Hot Shutdown Stations as follows: 5.1.4.1 Control Center Operator "A" - Hot Shutdown Control Panel 5.1.4.1.1 Establish communications on the Sound Power Phone System 5.1.4.1.2 Monitor available plant parameters on the Hot Shutdown Control Panel. 5.1.4.1.3 Start motor or steam driven Auxiliary F=ed Pumps and Feed Steam Gens. as required.
, 5.1.4.1.4 Control pressurizer pressure and level by a
manual control of pressurizer heaters, spray valves and Letdown valves. 5.1.4.2 Nuclear Plant Suoervisor - Electrical Equipment Room /R5 EL 43: Reactor Auxiliary Building 5.1.4.2.1 Open or check open Reactor Trip Breakers
- TC31-8 5.1.4.2.2 Place isolation switches in the isolate position on the following switchgear in the order listed:
- 1) 480V Bux 1A3 Pressurizar heaters
- 2) 480V Bux 133 Pressurizer heaters
- 3) 480V L.C. lA2
- 4) 4160V Bus LA3
- 5) 480V MCC LA5
- 6) 480V MCC 1A6
- 7) 480V L.C. 132
- 8) 4160V Bux 133
- 9) 480V MCC 136
- 10) 480V MCC 135
- 11) 480V MCC LAB
- 12) Isolation Panel LAB
- 13) Isolation Panel LA
- 14) Isolation Panel 1B
- 15) Evacuation Alarm Isolate Panel l
l Paga 4 of 28 E A EMERGENCY OPERATING PRCCEDURE 0030141 a REVISION 9 l
5.0 Instructions
?
5.1.4.2.2 Assist CCO operator "A" in monitoring unit parameters from Hot Shutdown Control l . Panel. 5.1.4.3 Control Cancer coerator "3" - Turbine Operating Level 5.1.4.3.1 Locally trip or verify tripped Unie No. 1 Turbine. 5.1.4.3.2 Verify Turbine Stop Valves and Control Valves are shut, and if not, initiate turbine trip from turbine front standard. 5.1.4.3.3 Proceed to Turbine Building Switchgear Room and establish communications on the Sound Powered Phone circuit. 5.1.4.3.4 Place Isolate switches to isolate position on 4160V Bus lA2, 132 Sus feeders, 6000V Bus lAl, 131 Bus feeders. 5.1.4.3.5 Shutdown LA & 13 Steam Gen. Feed Pumps, lA & 13 Heater Drain Pumps and one conden-sate pump by opening their respective breakers. - -
- CAUTION: Insure that one condensate pump remains in service.
5.1.4.4 Nuclear Operator - Reactor Auxiliary Building 5.1.4.4.1 Place isolation switches in isolated / local position on 4160V Sus LA3, 480V L.C. LAB 5.1.4.4.2 Proceed to D.G. Bldg. and place isolation switches on A & B Diesel Control Panels in isolate position. 5.1.4.4.3 Proceed to charging pump area and establish communications on the Sound Powered Phone circuit. g;
- t
Paga 3 of 28 t EMERGENCY OPERATING PDOCEDURE 0030141 l REVISION o i l
5.0 Instructions
(con't) 4 0 5.2 Subsequent Action l 5.2.1 Maintain pressurizer level at the "0" load setpoint. 5.2.2 Maintain pressurizer pressure at approximately 2100 psia. 5.2.3 Maintain Reactor Coolant System temperature at or below 5320 F (lA cold leg temp) by use of atmosphere steam dump and/or selective shutdown of Reactor Coolant pumps. 5.2.3.1 Shutdown Reactor Coolant pumps as required by opening the Reactor Coolant pump breakers in the turbine building switchgear roem. 5.2.5 Maintain steam generator level at the "0" load setpoint by operation of the auxiliary feedwater pumps and discharge valves to the steam generators. 5.2.6 After RCP coast down, shut down reactor coolant pump bearing lif t pumps as required, by opening breakers in the Reactor Auxiliary Building Electrical Equipment Room (MCC 1A5, 135, lA6, 136) and reclosing the breakers after one =inute. 5.2.7 Isolate steam generator blowdown by manually efosing isola- , tion valves at che closed blowdown heat exchangers(valves ' 23-112, 23-113, 12-137, 23-138). 5.2.8 When turbine speed decreases to "0" RPM, verify that the turning gear oil pump and the turning gear are in operation. 5.2.9 Periodinally check the habitability of the main control room and when conditons permit, reoccupy the Control Room. Return isolation switches to normal for switches and controls that are operational and maintain the Unit at hot standby until a complete evaluation has been made. 5.2.10 If Control Room accessibility is not possible, make pre-parations to place the Unit in a cold shutdown condition by utili=ing Operating Procedure OP 0030127 Reactor Plant Cooldown - Hot Standby to Cold Shutdown, as a guide and substituting local manual operations where required. NOTE: Prior to depressurization below 1600 psia, a manual blocking of all equipment associated with SIAS must be accomplished to prevent SIAS actuation. l l t t - ,
Page 6 of 28 EMERGENCY OPERATING PORCEDURE 0030141 REVISION 9 ISOLATION StTITCITES f Isolation Panel 1A - Auxiliary Bldg. Electrics 1 Equipment Room I m
- 1. SS/lS9-1 Auxiliary Spray Valve
- 2. SS/158 Letdown &- Spray- Valves Control has
- 3. SS-3/603 S.G. lA Press. & Level Indication
- 4. SS-1/603 S.G. lA Atmospheric Steam Dump Control
- 5. SS1/380 S.G. LA Level (wide range)
- 6. SS/130 Pressuri:er Level and. Press. Indication
- 7. SS-1/157 Letdown Isolation Valve
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3 Paga 7 of 28 I J 4 FLORIDA POWER & LIGHT COMPANY - ST. LUCIE UNITlil '
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EMERGENCY OPERATING PP.CCEDURE C030141 \' -
~
REVISION 9 ISOLATION SWITCHES . . , , s '. g
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,.l y 480 V Bus IA3 - Pressurizer heater bus, , ,
. 1 Auxiliarf building Electrical Equipment Room ,
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. FLORIDA POWER & LIGHT COMPANY l\-
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-x" ST. LUCIE UNIT #1 i
iEMERGENCY OPERATING PROCEDURE 0030141 [? REVISION 9
& ISOLATION' SWITCHES 480'V Bus 133 - Pressurizer heater bus, Auxiliary bldg. Electrical
- Equipment Room "
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- 1. Heater Bank P-2 4 -
- 2. Heater Bank B-4
- 3. Heater Bank B-5 J
- 4. Heater Bank B-6 s
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Page 9 of 28 DERGE:!CT OPERATING PROCEDURE 0030141 REVISION 9 4 i 1
. lA2 480V Load Center - Auxiliary Building Electrical Equipment Room > ;
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- 1. SS Transformer 1A2 (
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; 2. Bus Tie to 480V IAB
, 3. Air Recire Fan RVS LA ' 4. Air Recire Fan HVS 13
- 5. Charging Pump 1A 4
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l Page 10 of 28 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 REVISION 9 ISOLATION SWITCHES 4160 V Bus lA3, Auxiliary Building Electrical Equipment Room ].
- 1. "A" HPSI pump
- 2. "A" LPSI pump
- 3. "A" Containment Spray Pump
- 4. Feed to Pressurizer Heater Transformer 1A
- 5. "A" Component Cooling Pump
- 6. "A" Intake Cooling Pump
- 7. Feed to 4160 V Bus LAB S. Feed from 4160 V Bus lA2
- 9. Feed to 480 V Station Service Transformer 1A2
- 10. Feed from Emergency Diesel "A" - *
- 11. "A" Auxiliary Feed Pump . .
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Page 11 of 28 5 FLORIDA POWER & LIGliT COMPANY s ST. LUCIE UNIT #1 l l EMERGENCY OPERATING PROCEDURE 0030141 p' REVISION 9 (' L ISOLATION SWITCHES MCC 1AS Isolation Switches - Auxiliary Building Electrical Equipment Room
- 1. V-2514 - Makeup bypass to charging pumps
; 2. MV-14 Air Recirculation Cooler inlet Header "A"
- 3. MV-14 Air Recirculation cooler outlet Header "A"
- 4. MV-09 Auxiliary F.W. pump "A" discharge to "A" Steam Generator 4
- 5. MV-09 Auxiliary F.W. pump "A" discharge to "B" Steam Generator f
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Page 12 of 28 I FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 ' f EMERGENCY OPERATING PROCEDURE 0030141 REVISION 9 i ISOLATION SWITCHES , i MCC 1A6 Isolation Switches - Auxiliary Bldg. Electrical Equipment Room I mand
- 1. Boric Acid Makeup Pump 1A
- 2. Boric Acid Makeup Pump 1B
- 3. HVA-3A - Control Room Outdoor Air Conditioner J
- 4. HVE-6A - Shield building Exhaust Fan
- 5. HVE-13A - Control Room Booster Fan i
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Paga 13 of 28
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EMERGENCY OPERATING PRCCEDURE 0030141 REVISION 9 L=. . I ,
' I :
4 9 . I i 132 480V Load Center - Auxiliary Bldg. Elect. Equip. Room { i j
- 1. SS Transfor:ner 132 i m
4
- 2. Bus Tie to 480V 1AB
- 3. Air Recire Fan HVS 1C l
- 4. Air Recire Fan HVS 1D i
j 5. Charging Pump 13 i ' 1 I i 1 l 1 I l h e e e S e i i J d 9 E 4 1 t t -
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Paga 14 of 28 i i 1-1 FLORIDA POWER & LIGHT COMPANY ! ST. LUCIE UNIT 11 EMERGENCY OPERATING PS.0CEDURE 0030141 REVISION 9 ISOLATION SWITCHES men' , 4160 V 3us 1B3 - Auxiliary Building Electrical Equipment Room
- 1. Feed from Emergency Diesel "B"
- 2. Feed to 480 V Station Service Transformer 1B2
- 3. Feed to Pressurizer Heater Transformer 1B
- 4. "B" Component Cooling Pump S. "B" HPSI pump
- 6. "B" LPSI pump
- 7. "B" Containment Spray pump
- 8. Feed to 4160 V Sus LAB
- 9. "B" Intake Cooling Pump .
'10 . Feed from 4160 V Bus 132 ,
11 "B" Auxiliary Feed Pump. l
i Pags 15 of 28 FLORIDA POWER & LIGHT COMPANY tj ST. LUCIE UNIT 11 - I EMERGENCY OPERATING PROCEDURE 0030141 REVISION *9 l ISOLATION SWITCHES l l' MCC-136 - Auxiliary Building Electrical Equipcent Room
- 1. HVE-6B - Shield building Exhaust Fan
- 2. HVA-3B - Control Room Air Conditioner
- 3. HVE-13B - Control Room booster fan i
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. 1 Dage 16 of 28 i
FLORIDA POWER & LIGHT CCMPANY . ST. LL'CZ UNIT #1 l EMERGENCY OPERATING PROC 9URE 0030141 h REVISION 9 11 E ISOLATION SWITCHES j d MCC 135 - Auxiliary Building Electrical Equipment Room
- 1. V-2508 - BA Tank 13 Gravity Feed
- 2. V-2509 - BA Tank 1A Gravity Feed.
- 3. MV-09 Auxiliary F.W. pump "B" discharge to "B" S.G.
- 4. MV-14 Air Recirculation Cocler OUTLET Hdr. "B"
- 5. MV-14 Air Recirculation Cooler INLET Edr. "B"
- 6. V-2504 - RWT to charging pumps.
I 7. MV-09-14. e 0 e I I i i . .
Page 17 of 28 I FLORIDA POWER & LIGHT COMPANY 'b a Y ST. LUCIE UNIT #1 ; 3 EMERGENCY OPERATING PROCEDURE 0030141 ., U REVISION o b 5 I ISOLATION SWITCHES f MCC-1AB - Auxiliary Building Electrical Equipment Room 8ikms
- 1. HVA-3C - Control Room Air Conditioner, Indoor Unit.
- 2. MV-09 Auxiliary Feed Pump IC discharge to "A" Steam Generator
- 3. MV-09 Auxiliary Feed pump IC discharge to B 9 team Generator
- 4. MV-14 CCW discharge Valve - A Edr.
- 5. MV-14 CCW discharge valve - B Hdr.
- 6. MV-14 CCW discharge Valve - A Hdr.
- 7. MV-14 CCW discharge Valve B Hdr.
- 8. MV-08-13 "A" Stm HDR Supply Viv to "lC" Aux F.W. Pump
- 9. MV-08-14 "B"*Stm HDR Supply Viv to "lC" Aux F.W. Pump ,
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1 EMERGENCY OPERATI'iG PROCCURE 0030141 REVISION 9 ISOMTION SWI.JEES Isolation Panel LAB - Auxiliary Bldg. Electrical Equipment Room
+
- 1. Auxiliary WP 1C Turbine Governor and Speed Indication SS/631
- 2. Auxiliary FWT 1C Stop Valve ss/632 4
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Page 19 of 28 ., CLERGENCY OPERATING PROCEDURE 0030141 P REVISION 9 Q . ISOLATION SWITCHES i t! b
)
l mmma Isolation P,anel 13 - Auxiliary Building Eleef;rical Equipment Room
- 1. SS-4/604 SG L3 Press. & Level Indication
- 2. 5S-2/603 Atm. Sem. Dump Control
- 3. SS/189-2 Aux. Spray Valve
- 4. SS-2/157 Letdown Stop Valve
- 5. SS2-380 S.G. 1B Level (wide range) e O
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i Page 20 of 28 EMERGENCY OPERATING PROCEDURE 0030141 .
'E REVISION 9 !
3 h 5 ISOLATION SUITCHES Isolation Panel, Cornnunications Roon - Reactor Auxiliary Bldg. m
- 1. Fire Alar:n/ Site Evacuation - Control Console, Isolation Switch t
- 2. Control Room PA Isolation Switch
- 3. Code Call Isolation Switch.
l l i .i e 1 . . . j- . 1 . ,i e 1 9 0 n l ll 1 y y,- .c - - 9 % .g + -.g.y. -- , .-.
Pags 21 of 28 FLORIDA POWER & LIGHT COMPANY , f ST. LUCIE UNIT ill ! 0 EMERGENCY OPERATING PROCEDURE 0030141 's REVISION 9 fr ISOLATION SWITCHES ; i I summi 4160 V Bus LAB - Ground floor Reactor Auxiliary building
- 1. "C" HPSI pump -
" Local" Switch Position
- 2. "C" Component Cooling Pump -
" Local " Switch Position
- 3. "C" Intake Cooling Pump -
" Local" Switch Position
- 4. Feed from 4160 V Bus lA3
- 5. Feed from 4160 V Bus 133 G .
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Page 22 of 28
'i' DfERGENCY OPERATING PROCEDURE 0030141 REVISION 9
*) :
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1AB 480V Load Center - Reactor Auxiliary Building - Ground floor
- 1. Bus tie to 480V 1A2
- 2. ' Charging Pump 1C i
{- 3. Bus Tie to 480V Swgr 1B2 4 l 1 1 . e e N e i 5 l I o 5 {l \
Paga 23 of 28 l FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 p,
- EMERGENCY OPERATING PROCEDURE 0030141 l
REVISION 9 i / ! ISOLATION SWITCHES ti y tj [ h l A. Diesel Generator Control Panel i'
- l. Voltage Control i 2. Frequency Control j 3. Start Circuit 4
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_=. __ . - - . .m. - - ._ _ Page 24 of 28 i FLORIDA POWER & LIGHT CCMPANY h ST. LUCIE UNIT #1 I MERGENCY OPERATING PROCG URE 0030141 ! f' REVISION 9 i, ISOLATION SWITCHES g B. Diesel Generator Control Panel
- 1. Voltage Control t
- 2. Frequency Control i
i 3. Start Circuit i e l i I r T f 0 e e . e e , . 4 1 1 l-l 1 I
I l nage 25 of 28 ' FLORIDA POWER & LIGHT COMPANY - ST. LUCIE UNIT di i EMERGENCY OPERATING PROCEDURE 0030141 REVISION 9 , ISOLATION SWITCHES f. I 4160 V Bus 1A2 - Turbine Building e Switchgear Room m L. Feed to 480 V Station Service Transformer lAl
- 2. Feed to 4160 V Bus LA3
- 3. Feed from S.U. Transformer LA 8
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_ .. - . . - . =. ._ .- . .. Pags 26 of 2.8 i ! FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT !/1 EMERGINCY OPERATING PROCEDURE 0030141 REVISION 9 ISOLATION SWITCHES I il 4 6900 V Bus lAl - Turbine building l"t! 1 Switchgear Room
- 1. Feed from S.U. Transformer LA 4
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Pags 27 of 28 FLORIDA POWER & LIGHT COMPANY DERGEN bP N PO URE 0030141 , f REVISION 9 4 ; . ISOLATION SWITCHES d, y 4, ic 4160 V Bus 132 - Turbine Building Switch Gear Room
- 1. Feed to Station Service Transformer 1B1
- 2. Feed to 4160 V Bus 133
- 3. Feed from S.U. Transformer 1B e
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- Page 28 of 28 FLORIDA POWER & LIGHT COMPANY
[ l ST. LUCIE UNIT f1 EMERGENCY OPERATING PROCEDURE 0030141 , 4 REVISION 9 % { ISOLATION SWITCHES '1 J l
!! l 6900 V Bus 131 - Turbine Building il :
i f Switchgear Room L
- 1. Feed from S.U. Transformer 1B i
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Psga 1 of 27 FLORIDA POWER & ', IGE'" COMPANT ' ST L CIE ?LANT CICT 1
- {
EMERGENCT OPERAI!NG ?RCCDURE 0120040 REVISICN 9 i
1.0 Iicle
' m ; NAIURAL CIRCL'LATION/COOLDOWN i ' 2.0 Approval-Reviewed by Plant Nuc' Safety Coinsictee M 4 V I 19 Approved by M. . . . w Plant Manager >s'ft./A'h/ D / 8 19 4 Revision 9- Reviewed 57 Facili:f Review Group ' 2 ~/2- 19 72:
Approved 57 A ApW//d ?lant Manager' T--' 43 - 19 h
- - $-~ -
3.0 Purcose and Discussion: 3.1 Purpose
- 1. This procedure provides instructions to the operator in the event of a tocal loss of Reactor Coolant Pump (RCP) flow to tha reactor core.
- 2. This' procedure also providas guidance :o the op"er,ator'in '
, , the eveur. chat the plant nust be coolad devn using na: ural ,
circulation flow.
, 3.2 Precautions - See- Appendix A.
l, 3.3 Discussion - See Appendix 3. l 4.0 Svrotoms:
'- 4.L Lass. of of f-site. power.
- 4. 2. Loss of or low voltage on. 6.9 KV busses as indicated by:
- 1. 6.9 K7 switchgear LA1. 13L differential current trip.
- 2. 6.9 K7'switchgear 1A1,131 UNDERVOLTAGI alar:n.
! 4.3 RCP'0VERLOAD alarz i
, 4. 4. REACTOR C00LANI LOW FLOW channel pre-trip alarn.
4.5 REACTOR COOLANT LOW'FLCW channel. trip. I. ! : f l ! FOR INF00 MAT 00 ONLY This document is not cont olled. Refo e use,
. v.rify information wah a con + rotted docum.g I
. . ~ _ . - . . .-
,..% ^
Pags 2 of 27 EMERGENCY OPERATING PROCEDURE 0120040 Rev 9 NATURAL CIRCULATION /COOLCOWN
4.0 Symptoms
(cont) w
; 4.6 Loss of Component Cooling Water (CCW) flow to RCPs for 4 .i greater than 10 sinutes, requiring :nanual trip of all four
- pumps.
l . i 4.7 Valid SIAS-CIS caused by low RCS pressure, requiring all RCPs to be tripped after all Control Element Assemblies have been i inserted for 5 seconds. , 8 9 j . . .
- e l .
6 i l i 8 4I 1
Pegs 3 of 27 EMERCENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN e i 4
5.0 Instructions
w j , 5.1 Automatic Action
- 1. Reactor coolant low flow reactor trip (Setpoint: 95% of full RCS flow).
i 5.2 Immediate Operator Action
- 5.2.1 Carry out immediate operator actions for reactor trip l as follows:
?
- 1. Trip the turbine and reactor manually.
- 2. Ensure all CEA's are fully inserted and reactor j trip breakers are open.
- 3. Verify decreasing reactor power level, 1
i 4. Ensure the turbine valves are closed.
! 5. Ensure generator field and 240 KV breakers are open.
- 6. Ensure transfer of electrical power from a,uxiliary transformer (s) to startup transformer (s)
I.
! OR 1
g Ensure that the diesel generators have started and
, are feeding emergency busses, and are not overloaded.
- 7. Close MV-08-4, MV-08-6, MV-08-8, and MV-08-10 (MSR
, Reheat Block Valves).
- 8. Ensure that the Main Feedwater (MFW) System is re-storing or maintaining steam generator level, and that FCV-9011 and FCV-9021 (MFW Regulating Valves) are closed, and FCV-9005 and FCV-9006 (MFW'15%
Bypass Valves) open to approximately 5% of full l load flow. 9L. Initiate Auxiliary Feedwater (AW) flow to both steam l generators, and ensure flow to both steam generators. I' NOTE: If 'A' and 'B' AFW pumps are in operation and l 'C' AFW pump is not needed to restore steam generator
. levels to normal levels, place the AFW AUTO START BY -
l PASS switches in BYPASS. I e _ _ we. e.m- . m e--+ -* **-
. _ . . _ c._ _ . _ . _ __. _ _ _ _ . . . _ . _ - _ . . _ . . . . _ . . _ - _ _ _ _ - . . - . . - - - -
i Paga 4 of 27 EMERGENCY OPERATING PROCEDURE 0120040, REV 9 NAl' URAL CIRCULATION /COOLDOWN
5.0 Instructions
(Cont) I 5.2 (Cont) l 5.2.1 (cont) )
- 9. Ensure that Tav is being reduced to reference setpoinc by the steam dump valves to the condenser. If the bypass valves or the condenser are not available, use the atmospheric dump valves.
- 10. If any of the above automatic functions have failed to occur, manually initiate that, function.
5.2.2 Verify that shutdown margin (SDM) is >5.0% AK/K. If SDM_
. is less than specified, emergency borate the RCS until SDM , is > 5.0% AK/K.
5.2.3 continue to perform in parallel with this procedure any applicable operator actions that are required by the initiating event procedure (s). 5.2.4 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator". R9
! 5.3 Subsequent Actions i i 1 5.3.1 Establish and maintain hot let temperature (T h) at least <
20*F below the saturation temperature corresponding to RCS pressure (refer to Figure 1) by doing the following:
- 1. Operate pressurizer heaters or auxiliary spray to increase or maintain pressurizer pressure, and to provide sub-cooling margin.
- 2. Increase turbine bypass or atmospheric steam dump flow to reduce or maintain RCS temperature and prevent lif ting
. secondary safeties.
5.3.2 Verify that the pressurizer level control system is functioning . to maintain pressurizer level. If necessary, manually operate charging and letdown to restore and maintain normal pressurizer level. If operable charging pumps cannot restore RCS inventory and pressurizer level, observe RCS and containment parameters I for indications of a LOCA. 1 4 5.3.3 Restore and maintain steam generator levels at approximately 65%. I When feeding the steam generators use caution to avoid excessively cooling the RCS. CAUTION: Do noc exceed a cooldown rate of 750F/hr. 'i - 5.3.4 Verify by the following indications that natural circulation 'j* flow has been established within approximately 15 minutes after RCPs were tripped: t .
- 1. loop AT (Th - T )eless than normal full power T (.<46 F).
l
; R9 (
Paga 5 of 27 i., ; l 1 EhERGENCY OPEIuTING PROCEDURE 0120040, Rev 9 .! NATURAL CIRCULATION /COOLDOWN $ 4 J Q
5.0 Instructions
(cont) g 1 m 5.3 (cont) 5.3.4 (cont) t
- 1. (cont)
NOTE: The effective core 4T with only one steam generator in operation is determined as Th-Te where core Tc = 2x(Tc operating loop) + T. non-operating loop ors 3
- 2. Cold leg temperatures (Tc) constant or decreasing.
- 3. Hot leg temperatures (Th) stable (i.e. , not steadily increasing).
- 4. No abnormal differences between Th RTD's and core
, thermocouples.
5.3.5 Confirm boron concen*. ration in the RCS by. sampling from as many different points as possible. 5.3.6 Maintain the plant in a stabill:ec condition based upon auxiliary plant systems availability (e.g. , condensate inventory).
~
, 5.3.7 If one or more RCP's are restored toan operable condition within 10 minutes, start an RCP in each loop if the following criteria are satisfied:
- 1. At least ene steam generator is removing heat from the RCS.
r 2. Pressurizar level and pressure are responding normally
; to the Pressurizar Level and Control System.
- 3. The RCS is at least 20*F subcooled (refer to Figure 1).
- 4. The yellow PERMISSIVE light on the associated pump ,
j control switch is lit.
- 5. No indication of voids in RCS are present.
i i
. , . . p
^~~
Page 5 of 27
. l EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 ,
NATURAL CIRCULATION /C00LDOWN I] ' ,\
5.0 Instructions
(cont) , m 5.3 (cont) 5.3.8 If all four RCPs can be returned to operable status within 10 minutes, power operation may be resumed under the direction of the Nuclear Plant Supervisor. If RCS cooldown is required under these conditions, the cooldown should be accomplished using forced circulation. 5.3.9 If required to conduct a plant cooldown to shutdown cooling (SDC) conditions using natural circulation, . . proceed as follows: '
- 1. Establish as stable plant conditions as circumstances permit. . .
t
- 2. Verify that RCS boration has progressed to the point that the required SDM can be maintained during the cooldown.
- 3. Commence supplying makeup water to the Condensste, i Storage Tank. If off-site power is not available', ,
place the Water Treatment Plant in service as per .
. Appendix C. -
- 4. Commence an RCS cooldown by utilizing one of the following methods:
' a. If the condenser is available, use the Steam' ! itmp Bypass System and Main or Auxiliary Feedwater.
l Cf the condenser is not available, use the at-caspheric dump valves and Main or Auxiliary, i Feedvater. i l
- 5. Continuously verify natural circulation flow through-out the cooldown- process, f 6. Observe all available indications to determiae
; conditions within the RCS.
1
- a. Use the Subcooled Margin Monitor (SMM 1 Th, Tc, l and RCS pressure to verify that the RCS is sub-cooled. 8
'I i ;
/
1 I k ,
- {,
._. a _ . _ _ __ _ _ _ - _ ..- _ . . _. __. _ _ ..._ _ _ . . _ .
, ?' , l Pagn 7 of 27 i EMERGENCY OPEiMTING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN j 4 l
5.0 Instructions
(cont) l 5.3 (cont) 5.3.9 (cont)
- 6. (cont)
- b. Figure 1 or the nomograph on RTGB-103 should be used for comparison with the SNM; subcooled
, margin can also be determined by subtracting
. Th from pressurizer temperature (TE-1101) .
d
- c. Incore thermocouples, recorded on the DDPS, can also be used for indication of Th.
- 7. Establish and maintain a RCS cooldown rate of 50*F/hr.
(See Figure 2). The highest RCS cold leg temperature shall be plotted everv 30 minutes on a copy of Figure 4+ . Ihe RCs temperature anc pressure snali ce de-termined to be within the lic.its of Technical Spec-ification Figure 3.4-23 at least once per 30 minutes during cooldown.
' ' ' ^
- 8. The pressurizer water phase shall be recorded on ,
Figure 5 and plotted every 30 minutes on Figure 4. This temperature shall also be compared isith the lowest spray water temperature to ensure that differential temperature does not exceed 350*F.
! 9. Maintain RCS pressure above and to the right of the curve values shown on Figure 3.
l
- 10. During the cooldown, maintain a rinimum of 20*F
; subcooling by the following methods (listed in order j ; of preference):
l
, a. Manual control of pressurizer heaters and aux-1 iliary spray.
i NOTE: Use only one charging pump.
- b. Operating charging or HPSI pumps.
- 11. During- the cooldown, maintain pressurizer level by g
the following =ethods (listed in order of preference):
. [,-
-,= a. Control charging and letdown.
- b. Operating HPSI pumps.
l
- --n -- -.- -
4
. _ _ _ _ .....L _ . _ . . _ _ _.
Pagt 8 of 27 l EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN
5.0 Instructions
(cont) In=== 5.3 (cont) 5.3.9 (cont)
! 12. Monitor the available condensate inventory and replenish the CST as required.
CAUTIO'N: Condensate Storage Tank volume shall be maintained 116,000 gallons per Technical Speci-
, fications 3.7.1.3. If this limit cannot be main-tained, proceed to Appendix E.
- 13. During RCS cooldown and depressurization, perform the evolutions specified in Appendix D.
- 14. During RCS depressurization monitor for void for-mation in the reactor vessel upper head region.
Indications of possible void formation include:
- a. RCS t.eperature iTsat for the correspondlag RCS pressure.
- b. A, pressurizer level increase significantly
. greater than expected while operating aux-
. iliary spray.
- c. A pressurizer level decrease while operating
; charging.
i i d. If the Pressurizer Level Control System is in
- automatic, an unanticipated letdown flow greater than charging flow.
l
. 15. If voiding in the RCS is indicated, perform the ' following:
I
- a. Isolate letdown by closing 7-2515 and V-2516 (Letdown Containment Isolation),
i
- b. Stop the RCS depressurization.
l
. c. Stop the RCS cooldown. , d. If possible, review and select one RCP in each loop for restarting.
l
, , ~ ' ' ' " " - " '
~
- _. .- _ . . _ _ _ _ . . . . _ _ _ . _ i i
l Pa;a 9 of 27 l EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN
5.0 Instructions
(cont) iW 5.3 (cont) 5.3.9 (cont) I t 15. (cont) i
- e. Repressurize the RCS to eliminate the void by operating pressurizer heaters or HPSI and charging pumps.
NOTE: If the EPSI or charging pumps are utilized to charge the RCS solid, the pumps should be stopped after solid RCS conditions are indicated.
- f. If required to continue the cooldown with the known presence of a steam void in the reactor vessel head, proceed using the Fill and Drain method (Appendix E).
~
- g. When conditions permit, re-initiate letdown and
' resume depressurization to SDC initiation pressure. .
- 16. If off-site power has been lost, and it becomes -
necessary to augment the cooldown rata. refer to, Appendix F.
- 17. When RCS temperature reaches 325'F, =aintain the RCS at this temperature for an additional 20.4 hours j (See Figure 2).
- 18. Upon completion of the required " soak" period, 3
initiate SDC La accordance with Appendix G. I
$ .o "
-- - . _. _ _ . _ ~~ -
Pags 10 of 27
'I DfERGENCY OPERATING PROCEDURE 0120040, Rav 9 l
NATURAL CIRCULATION /COOLDOWN , I Figure 1 ' 3 SATURATION E i- 3000 2800 I /I 7 2000 SUPERCOOLED REGION I ll l 2400 2200 ,
// /
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' '^
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//
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. . . I i Page 14 of 27 i EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 L -
p NATURil. CfRCUI.ATION/C00LDOWN - t Y ;l t \ l dfl ^l ' f l .'l I.il" l >l I l .. l' l l I
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Y f, I_ "T . __. NOTE 2 - REACTOR VESSEL EELTLINE MATERIAL ----- 4: t, . N={.[.T_ .t :t: _ : 9 =t=::=C 10 YEAR RT m SHIFT = 133* F --- [ k [Mli-i5iMI~#l'~"$ t.*OTE 3- REMAINING PRES $URE ::OUNDARY
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- 0 0 100- 200 . ' 300 400 , 500 Goo INDICATED R EACTOR COOLANT TEf.t?ER ATURE T g .*F ,
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.- FIGunE 3.4-2b i '- ReactorCoelant System Pressure Tempersture Limitations ,;
for up to 10 Years of Futt Power Operatic.n ,
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~'
j P EMERGENCY OPERATING PROCEDURE 0120040, Rev I 9 __ NATURAL CIRCULATION /C00LDOWN -- - . i l l 3 j j' FIGURE 5 ,
-i DATE J Column 2 Column 3
- Difference j i THIE Column 1 Pressurizer Column 1 ;
Pressurizer Lowest Spray Temp Line Temp Press minus j every C Iumn 2 j; TIA 1103/1104 PIC 1103/1104
' 30 minutes TI-1101 (
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- Limited to 43500 and 750 -
- __ Operator Shifc l RCS TEMP AND PRESSURE SIL\LI. BE WIT 11IN LIltITS Operator Shift OF FIGURE 3.4-2b FOR EAC11 30 ItINUTE PERIOD. -
ShlfC I Operator l
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l r i Page 16 of 27 l l 4 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /C00LOOWN , APPENDIX A PRECAUTIONS l med
- 1. Natural circulation flow cannot be verified until the RCP's have stopped coasting down after being tripped.
- 2. Due to increased loop transit times, verification of plant re-sponses to a plant change cannot be accomplished until approximately 10 to 15 minutes following the action.
{ 3. After a cold shutdown boron concentration is attained in the RCS,
~
makeup water added to tha F.CS during the cooldown should be at least the same boron concentration as in the RCS to prevent any dilution of RCS boron concentration.
- 4. Once pressurizar cooldown has begun, pressurizer level indication
> decalibration will occur (indication on the normal pressurizer level indication will begin to deviate from the true pressurizer laval) .
Tha te=peratu-a c-?pensatiaa -errartien curve posted on the RTcR should be used to determine true pressurizer water level. Cold i callorated pressurizer level indication is also available for lower
, pressurizer temperatures.
- 5. Minimize the use of pressurizer auxiliary spray whenever the tem-perature differential between the spray water and the pressurizer is greater than 200*F. Any auxiliary spray cycle which results in d spray line temperature change of 650*F to 120*F in < 1.5 seconds shall be recorded in accordance with AP 0010134.
- 6. If pressurizar spray is not available, boron concentration in the t pressurizer may be lower than the RCS loop boron concentration. RCS bore a concentration should be increased to avoid being diluted below mir.imum requirements by a possible pressurizer outsurge.
- 7. If either the HPSI or LPSI pumps are utilized to collapse any steam voids in the RCS by charging the system solid, the pump (s) should be stopped after solid conditions are indicated. This will minimize the potential for any inadvertant flowpath from the RCS back to the Refueling Water Tank.
- 8. If the RCS is solid, closely monitor any makeup or draining and sny i system heacup or cooldown to avoid any unfavorable rapid pressure
{ excursions. 1 l 4 9. During all phases of the cooldown, monitor RCS temperature to avoid I exceeding a cooldown rate ) 100*F/hr. I l l'
* * - ey am g h , , , . a e
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Paga 17 of 27 t l l l EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 i l NATURAL CIRCULATION /C00LDOWN APPENDIX A (cont)
- 10. If cooling down by natural circulation with an isolated steam gen-erator, an inverted AT (i.e., Tc PTh) may be observed in the idle loop. This is due to a small amount of reverse heat transfer in the isolated steam generator and will have no effect on natural circu-lacion flow in the intact steam generator.
- 11. All available indications should be used to aid in diagnosing the event since it may cause irregularities in a particular instrument reading. Critical parameters must be verified when one or more confirmatory indications are available. -
i
- 12. When establishing auxiliary feedwater flow to the Steam Generators, use Steam Generator levels as well as header flowrates to ensure each Steam Generator is receiving auxiliary feedwater.
- 13. Condensate inventory should be monitored periodically to ensure that an adequate supply is available. Makeup to the Condensate Storage Tank should be started as soon as practical. If CST level decreases to <116,000 ;;211:ns , the plant should be '--diately cooled down utilizing the Fill and Drain Method (Appendix E).
O O e D 9 i
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Pags 18 of 27 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 . 3 NATURAL CIRCULATION /C00LDOWN APPENDIX 3 i n-m DISCUSSION Reactor Coolant Pump forced circulation and heat transfer to the Steam Generators is the preferred mode of operation for decay heat removal I whenever plant temperatures and pressures are above the Shutdown Cooling System entry conditions. The natural circulation capability at the St. Lucie Plant provides an emergency means for core cooling using the steam generators, if the RCPs- are unavailable. Natural circulation is governed by decay heat, component elevations, primary to secondary heat transfer, loop flow resistance, and voiding. Component elevations at So Lucie Plant are such that satisfactory natural circulation decay heat removal is obtained by density differences be-tween the bottom of the core and the top of the steam generator tube sheet. An additional contribution to natural circulation flowrate is the density difference obtained as the coolant passes through the Steam Generator U-tubes, but this is not required for satisfactory natural , circulation. datural circulation is assurea even if cne U-tubes are partially uncovered on the Steam Generator secondary side. Because of the temperature distribution in the Steam Generator U-tubes, there is no degradation in primary to secondary heat transfer as long as the secondary level covers at least 1/3 of the~ tube height. By ensuring that the loop 4T is less than the full power AT, the power-to-flow ratio is assured to be less chan 1.0 during natural circulation. t Satisfactory natural circulation heat removal can be obtained with either ! one or two Steam Generators. Unequal auxiliary feedwater to the Steam i Generators will not lead to unsatisfactory natural circulation as long
, as all of the decay heat is being removed through the Steam Generators.
I f
! Assurance that the RCS is being maintained in a subcooled condition can be obtained as follows. With the Subcooling Margin Monitor (SMM) operating normally, the nomograph on RTGB 104 is used in conjunction with the SMM i to eliminate dependence on a single instrument. With the SMM inoperable, ; reference to the nomograph utilizing control room indication such as i hot leg temperature, pressurizer pressure, and incere thermocouples will determine the margin to saturation. Subcooling margin can also be de-carmined by subtracting hot leg temperature from pressurizer temperature i (TE-1101). , During normal plant operation under conditions of forced circulation j flow, there is only a small flow of coolant in the reactor vessel head I area. During periods of natural circulation, there is little, if any, effective flow. If the RCS is cooled down using natural circulation, it is possible to generate a steam void in the reacror vessel head when , saturation conditions develop. These conditions can be produced by the temperature sustained by the retained metal heat and decreased RCS pressurs during cooldown.
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Page 19 of 27 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 < NATURAL CIRCULATION /COOLDOWN APPENDIX 3 (cont) , Analyses have demonstrated that the upper reactor head region fluid can ""d be cooled to Shutdown Cooling System (SDC) entry conditions without void formation using a hot leg temperature cooldown rate of 50*F/hr in approx-i=ately 14.2 hours. In order to provide add'itional conservatism, this procedure directs that a cooldown rate of about 50*F/hr to 325*F be utilized, followed by a soak of 325*F for 20.4 hours for a total cooldown time of approximately 25.7 hours from cooldown initiation. (See Figure 1). The condensate supply required for this cooldown is 270,500 gallons. Makeup water can be supplied from the Water Treatment Plant and the two 500,000 gallon City Water Storage Tanks, or Treated Water Storage Tank. Pumping capability from all sources can be supplied from the diesel generators. An alternative to the above cooldown procedure is the fill and drain method (See Appendix E). This method may be employed should an er.teremely low probability event occur which could cause a loss of condensate makeup capacity or require a rapid RCS de-pressurization rate. It provides for cooling of the upper reactor vessel head region by using auxiliary spray to the pressurizer to lower RCS pressure and create a void in the upper head. Voiding in the upper head flushes hot upper head fluid into the coeler RCS rhere it nises with RCS water. The rater flushed out of the upper head will cause a surge of water from the RCS into the pressurizer. The process is halted by stopping the spray. The insurge compresses the pressurizer steam space, raising the pressure, thus stopping the insurge and halting flashing in the upper head,. Charging to the RCS will then force fluid into the upper head due to the elevation difference.between the reactor vessel upper head and the pressurizer. Mixing of colder loop water with the hot upper head cools the upper head and causes an outsurge from the pressurizer. The process is continued until the upper head is solid. The cycle is then repeated until RCS temperature and pressure have been reduced to SDC entry conditions. The above procedure has been analyzed and performed successfully twice at St. Lucie and is considerea a safe, alternative metnoa of natural circulation cooldown. t i i
- t
,_ 4 ,
Pags 20 of 27 \ 1 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 M d NATURAL CIRCULATION /COOLDOWN : 1 A APPENDIX C - PLACING WATER TREATMENT PLANT IN SERVICE E DURING LOSS OF OFF-SITE POWER g NOTE: Makeup to the Condensate Storage Tank (CST) should be initiated as soon as diesel generator loading allows. [ 1. Strip the non-vital 4.16 KV busses. lA2 IB2
. NOTE: All should have opened automatically.
- 2. Insert the Sync Plug and close the 4.16 KV non-vital breaker. 1A2-20109 132-20309
- 3. Hold the control switch closed while closing 4.16 KV vital breaker. 1A3-20209 133-20411
- 4. Strip the non-vital 480V Load Center. lAl 131
- 5. Close the 4.16 KV non-vital breaker. 1Al-20110 1B2-20310
- 6. Close the non-vital Load Center breaker. 1Al-40103 131-40403
- 7. Strip the 480 V MCC. IA4 134
- 3. Close the 480 V Load Center breaker. 1Al-40113 131-40413
- 9. Start only equipment required to transfer water co che CST.
NOTE: If a shortage of water persists in the CST, it is permissible to overide, as necessary, any automatic trips (e.g., con-ductivity, silica, etc.). .
~
- 10. Water may ilsa be supplied to the ' CST from the Treated " Water Storage Tank as follows: ,
- a. Complete steps 1 thru 6 above .
, ,b . Strip the 480V MCC 1A3 133
- c. Close the 480 V Load Center breaker. 1Al-40116 1B1-40412
- d. Align valves to pump from TWST to CST.
- e. Close breakers and start treater
, water transfer pump (s) la and/or 13 1A3-41016 133-41816
- 11. If the Water Treatment Plant cannot be placed in service, transfer I water directly from the City Water Tanks to the CST using a fire pump and a temporary fire hose.
NOTE: City Water Tanks should not be reduced below 300,000 gallons each, per Technical Specification 3.7.11.1. l g [ l [ l
Page 21 of 27 OfERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN ' i L
! 4 APPENDLX D
;w RCS COOLDOWN/DE-PRESSURIZATION CHECKOFF LIST
- 1. At RCS pressure of 1730 psig, isolate and bypass the following trans-mitters:
1.1 FT-2212 (Charging Header Flow Transmitter) ( NOTE: Close the valve on the transmitter marked HIGH SIDE, open the valve marked BYPASS, and close the valve marked LOW SIDE. 1.2 PT-2212 (Charging Header Pressure Transmitter) NOTE: Close its isolation valve.
- 2. At RCS pressure of 1700 psia, the SIAS Channel BLOCK PERMISSIVE annunciator will come on. Block Channels A and 3 of SIAS by turr.i ; tha key-ir.:..;1e,cked swiaL..; to the SLOC g,c.it.iec..
NOTE: If the channels have been blocked, the two annunciators SIAS ACTUATION CHANNEL A BLOCKED and SIAS ACTUATION CHANNEL B BLOCKED will come on.
- 3. At RCS pressure <1750 psia, align the NaOH System as follows:
3.1 Close and lock NaOH system injection header isolation valves: V-07255 V-07257
"-07271 ; V-07272 1 ! 3.2 De-energize the NaOH system admission valves after ensuring that they are closed:
SE-07-1A RTGB 106 TBCCC F31,32 i SE-07-1B RTGB 106 TBGG F31,32
~
SE-07-2A RTGB 106 TBCCC F49,50 SE-07-2B RTCB 106 TBGG F49,50 8
~ _ . - . ~ . . . . .-
Page 22 of 27 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /C00LD0k'N APPENDIX D (cont) ,,
- 4. At Steam Generator pressure of 685 psig, the MSIS ACTUATION CHANNEL A BLOCK PERMISSIVE and MSIS ACTUATION CHANNEL 3 BLOCK PERMISSIVE annunciators will come on. Block the MSIS channels by turning the
, key-interlocked switches to the BLOCK position.
NOTE: If the channels have been blocked, the two annunciators MSIS ACTUATION CHANNEL A BLOCKED and MSIS ACTUATION CHANNEL B BLOCKED will come on.
- 5. Prior to reaching RCS pressure of 1100 psia, unisolate and place in operation the standby pressurizer level control and letdown j pressure control valves.
- 6. When RCS temperature is <500*F and RCS pressure is <1500 psia, i perform the following:
6.1 Close the Safety Injection Iank discharge valves by placing the switch in the BYPASS CLOSE position and racking out its respective breaker: VALVE BREAKER , V-3614 41312 V-3624 41222 *
, V-3634 42033 , V-3644 42113 6.2 Close the Containment Spray (CS) pump discharge valves:
l V-07145 t
! V-07130 1-6.3 Close and tag the manual valves in the CS header:
V-07161 (A Edr) V-07164 (B, Edr) I 6.4 Close containment spray motor operated valves 1 MV-07-3A (A Edr) { MV-07-3B (B Bdr) i t
- t
Paga 23 of 27 l DERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN i APPENDIX D (cont) { I m!
- 7. When RCS pressure reaches 415 psia or RCS cold leg temperature reaches 275'F, annunciator SELECT LOW RANGE OPERATION will Come on.
l B 7.1 Close MOV-1403 and MOV-1405 (PORV Isolation) l 7.2 Select LOW RANGE on control switches for PORV-1402 and PORV-1404,
, and ensure that neither PORV opens.
7.3 Open MOV-1403 and MOV-1405 (PORV Isolation).
- 8. When RCS temperature reaches 325'F and RCS pressure reaches 260 psia, l' perform the following:
i 8.1 Remove the trip and close fuses on two HPSI pumps, and tag with caution tags.
- CTI: Ensure tha rc=aining "'";I pu=p is cpcratic.
8.2 Remove the trip and close fuses on the A and B CS Pumps, and tag with caution tags.
. 9. When RCS temperature reach'es 0 2'0*f, perform the following:
9.1" Remove the trip and close fuses on the remaining HPSI pump and tag with.. caution tags. , t 9.2 Tag out one charging pump such that no more than two charging
; pumps are available for dilution below 200*F.
l i 4 l 4 I t i, t
- 4 l
. .i..... . . - . . . . ~ . . . . -
l Page 24 of 27 g i ! i 1 EMERGENCY OPERATING PROCEDURE 0120040. Rev 9 ! ) NATURAL CIRCULATION /C00LDOWN l 4 ' l APPENDIX E j t RCS FILL AND DRAIN METHOD OF COOLING i REACTOR VESSEL HEAD REGION NOTE: This method of RCS cooldown should only be employed in the event 1 that rapid de-pressurization of the RCS is required, or Condensate I, Storage Tank level decreases below 116,000 gallons. CAUTION: During this evolution, pressurizer level is not a valid in-i dicator of RCS inventory during transient conditions. Care
; should be exercised to observe other parameters which would i indicate any loss of RCS inventory.
- 1. Take manual control of the charging and letdown system.
f
- 2. Lower RCS pressure by using auxiliary sprays into the pressurizer.
2 3. As voiding occurs in the upper reactor vessel head, a surge of water from the RCS will cause pressurizer level to increase rapidly. Ter-j minate auxiliary spray prior to pressurizer level increasing tv 70%
; indicated level.
- 4. Cool the upper reactor vassel head region by charging with a charging l pump to the RCS loop (s). Continue charging until either of the following conditions occur: -
- 4.1 Pressurizer level decreases to 30% indicated level E
4.2 The upper reactor head is charged solid. j NOTE: A solid upper head condition will be evident by an increasing i pressurizer level as charging to the loops is continued.
- 5. Repeat steps 1 thru 4 above until SDC entry conditions are established.
i i i 1 k
Page 25 of 27 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN l ,
! APPENDIX F AUGMENTED COOLDOWN WITH THE STEAM DL"@
BYPASS SYSTEM (SBCS) If the desired RCS cooldown rate cannot be attained, the SBCS can be used either by itself or in conjunction with the atmospheric dump valves.
, Since condenser vacuum will not be available, the following actions ! should be taken to place the SBCS in service:
I l 1. Call available maintenance personnel on site to remove the target 3 flange on a SBVS valve (preferably V-8803). NOTE: If no maintenance personnel are on site, call the Duty Call l
- Supervisor.
I
- 2. Isolate all other SBCS valves from the condenser (except the selected
. valve). ! 3. Jumper V-8803 by placing a jumper on termination box EM 104, leads ; 10 to 11 (located behind and in the lower portion of RRS #2 cabinet l , in RTGB-104). .
I .
- 4. Ruset the condenser vacuum interlock by deptessing the reset button
- I (on the outside of the RRS #2 cabinet) and observe that the condenser l vacuum interlock yellow light goes out, f
I NOTE: This will bypass the vacuum permissive and allow operation of V-8803 to atmosphere after removal of the target flange.
- 5. Place all SBCS controllers in MANUAL.
- 6. When the target flange for V-8803 has been removed and the vacuur interlock jumpered, menually adjust the controller for V-8803 to control RCS cooldown race.
. CAUTION: Do not exceed a cooldown race 175'F/hr. Ii t
?
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I Paga 26 of 27 EMERGENCY OPERAT'ING PROCEDURE 0120040, Rev 9 NATURAL CIRCULATION /COOLDOWN ! 1 l APPENDIX G . b INITIATION OF SHUTDOWN COOLING
- 1. Open V-3657 (SDC discharge to LPSI header) .
l 2. Open MV-3452 and MV-3453 (LPSI pump supply to SDC EK) .
- 3. Check to be open FCV-3306 (SDC EX bypass).
. 4. Close MV-03-2 (FCV-3306 bypass).
- 5. Open MV-03-1A and MV-03-13 (SDC recire warmup).
- 6. Open MV-3456 and MV-3457 (SDC EX isolation).
- 7. Check to be open V-3204 and V-3205 (LPSI mini-flow).
B. Check to be open V-3659 and V-3660 (Mini-flow header stop).
- 9. Start 1A and IB LPSI pumps.
- 10. Check to be closed V-3661 (Check valve leakage drain).
- 11. Open HCV-3615, HCV-3625, HCV-3635, and HCV'-3645 (LPSI isolatiop).
- 12. Open HCV-3618, HCV-3628, ECV-3638, and HCV-3648 (Check valve leakage control).
, 13. Open V-3459, V-3463, and V-07009 (RWT recire stop). ! 14. Check the boron concentration in the system after circulating for ten minutes. Continue circulation until the boron con-centration is a to the concentration in the RCS.
- 15. Close HCV-3618, HCV-3628 ECV-3638, and ECV-3648 (Check valve leakage control).
! 16. Close V-3459, V-3463, and V-07009 (RWT recire stop) .
- 17. Close HCV-3615. HCV-3625, HCV-3635, and HCV-3645 (LPSI isolation).
- 18. Close V-3657 (SDC EX discharge to LPSI header) .
i I 19. Continue to run the LPSI pumps to heatup the SDC system as
! much as practical.
I CAUTION: ENSURE LPSI PUMP MINIMUM FLOW IS MAINTALNED IN THE i< SDC SYSTEM WHEN ONE OR BOTH MINIFLOW VALVES ARE CLOSED. l l l , I 7 --,, _ _
Page 27 of 27 EMERGENCY OPERATING PROCEDURE 0120040, Rev 9 ! NATURAL CIRCULATION /CCOLDOWN APPENDIX G (cont)
\&
- 20. Verify flow on FI-3306 and close V-3205 (manual LPSI pump recire).
- 21. Close V-3204 (manual LPSI pump recirc).
- 22. Stop the A and B LPSI Pumps.
- 23. Close MV-3444 and MV-3432 (LPSI pump suction from RWT).
- 24. Close MV-03-1A and MV-03-13 (SDC recire warmup).
- 25. Check RCS pressure 4 265 psia, then open V-3651, V-3652, V-3480 and V-3481 (SDC return valves).
- 26. Open HCV-14-3A and HCV-14-3B (CCW to SDC HK).
- 27. Start A or B LPSI pump.
- 28. Slowly inch open either HCV-3625 or HCV-3635 in approximately 5% increments to bring the SDC system up to temperature.
" 29. Adjust FIS3306 to maximum flow in AUTO mode.
30,*When temperature has stabilized, slowly open V-3615, V-3625, V-3635, and V-3645 (LPSI discharge valves) and adjust FIC-3306 to control flow at 3000 gpm in AUTO.
! 31. Adjust HCV-3657 (SDC return) to maintain the desired cooldown race.
NOTE: When the cooldown is completed, all of the flow should be going through HCV-3657, and FCV-3306 should be closed. i l i i , i i s l 1 I l t l'
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Page 1 of '3 P l t FLORIDA PCWER & LIGHT CCMPANY . I ST. LUC I f1 NIT NO. 1 i J ZMERGINCY 0? ERAT 3G PRCCIOURE 0120041 RZ7 S!CN NO. 12 [ Y L
1.0 Title
STIAM GENERATOR TUBE LZ.E/7AI!.URE
2.0 Aceroval
Reviewed by: Plant Nuclear Safety Commi::ee b7 19 7J Approved by: p . //. /3 a., e - Fr/1/?lant Manager 6 21 19 7J Revision 7 Reviewed by FRG dr4 /<,m oer /Y 19"79 Approved by: d /J/Tng AGlant Manager /O - 1 19 7 9 Revision 12 Reviewed by FRG /'n ~ /[ 'l 19 <30. Approved by 4:P E,///h Planc M2:ager J= /c- 1982. 3.0 Pursoaa and Oiscussion: 3.1 '"ha purposa of this procedure is :o lis: :he indica:icas :ha: will enable the operacer to identify a steam Generacor Tube failure and to provide the ac:1on :o be :aken :o control the '
- ac.cident and si"4-4:e radioactice release :o che environ =ent.
3.2 Discussion
3.2.1 A Steam Generacer Tube Failure causes leakage of reactor coolant into the steam system. If the leakage exceeds the capacity of the charging pu=ps, pressurizer pressure will decrease rapidly, causing a ther=al sargin/ low pressure
- rip. The subsequen: cooldown following the reac:or rip conbined witn the continued leakage of reactor colant into the Steam Generator will cause a further reduction in pressuriser pressure and level, resulting in initiation of safety injection and concainmenc isolacion. The tube rup-Oure will cause a reduction in reac:or coolanc system volume and due to reactor coolant leakage into the steam generator, the affected steam generator level vill continue to increase after the feedwater block valves are closed by SIAS. The resulting decrease in RCS pressure and volu=e will resul: in :he RCS briefly being at saturation condi-tions. The possibility : hen exists for void for=acion in the reactor coolanc system.
FOR INFORMATION ONLY This document is not controlled. Before use, wify information with a controlled document. (
Paga 2 of 15 , EMERGENCY OPERATING PROCEDURE 0120041, REV. 12 STEAM GENERATOR TUBE LEAK / FAILURE j 3.0 P,urpose and Discussion: (Cont'd) l l ! 3.2 (Cont'd) w i 3.2.2 Operator action should be directed toward prompt isolation , of the affected Steam Generator, to minimize contamination of the steam system and prevent possible radioactive release to the environment. With the exception of a compound accident in which loss of power accompanies the Steam Generator Tube failure, steam is dumped to the condenser, rather than the atmosphere, to prevent gross release of contamination to the environment. Action must be taken to identify the affected Steam Generator as soon as possible and to isolate its feedwater flow to prevent water slugging the steam lines. 3.2.3 The Steam Generator Tube failure accident is most severe when it occurs at low power levels, due to the low inventory of water initially present in the pressurizer. 3.2.4 This procedure provides instructions for two cases, " Leak within the Capacity of the Charging Pumps" and " Tube failura" (axceeds Charging Pump Capacity).
4.0 Smotems
4.1, Unique to a Steam Generator Tube Failure / Leak: . 4.1.1 Steam Generator Blowdown Monitor Alarm. 4.1.2 Condenser Air Ejector Monitor Alarm. 4.2 Possibly Caused by a Steam Generator Tube Failure: 4.2.1 Decreasing Pressurizer Level, Backup Charging Pumps Start, Pressurizer Low Level Alarm, Pressurizer Heaters Deenergize. 4.2.2 Decreasing Pressurizer Pressure, Backup Heaters Energize, Pressurizer Low Pressure Alarm. 4.2.3 Initial Increase in Affected Steam Generator Level, Followed by Return to Programmed Level Setpoint. 4.2.4 Feedwater Flow Less Than Steam Flow on Affected Steam Generator. 4.2.5 Letdown Flow Decreasing. 4.2.6 Charging Flow to Regenerative Heat Exchanger Increasing. l
Page 3 of IJ DiERGENCY OPERATING PROCEDURE 0120041, REV. 12 STEAM GENERATOR TUBE LEAK / FAILURE
5.0 Instructions
5.1 Laak Within Capacity of Charging Pumps 3.1.1 I= mediate Automatic Action: l 5.1.1.1 A Steam Generator blowdown monitor alarm will actuate a high radiation alarm in control and signals to trip closed the blowdown and sample valves. 5.1.1.2 Letdown Level Control Valves close to minimum value. 5.1.1.3 Backup charging pumps are started as pressurizer level decreases. 5.1.2 Lamediate Operator Action: 5.1.2.1 Place additional charging pumps in operation, if not operating, to restore pressurizer level. 5.1.2.2 Notify System Dispatcher and reduce turbine load in i preparation for Reactor Shutdown if: 1 5.1.2.2.1 Tube leakage exceeds 1 GFM or, 5.1.2.2.2 The specific activity of the secondary
. system'is greatar than 0.10 uc/gm Dose.Eq I-131. -
NOTE: If either of these conditions exist be in at . least Hot Standby within 5 hours and in Cold Shutdown within the next 30 hours, per Standard Technical Specifications. 5.1.2.3 Determine affected steam generator, if possible, by: 5.1.2.3.1 Comparing Steam Generator levels. 5.1.2.3.2 Comparing Steam generators steam flow and feed flow. 5.1.2.4 Take manual control of atmospheric dump valve controller on affected steam generator, HIC-08-2A or HIC-08-23 and close atmospheric dump valve to zero percent valve position.
~
5.1. 2. 5 Check chac the condenser air ejector vent is aligned to the plant vent. 5.1.2.6 Ensure that steam generator blowdown valves, and sample isolation valves are closed. l
i Page 4 of 15 DiERGENCY OPERATING PROCEDURE 0120041, REV. 12 STEAM GENERATOR TUBE LEAK / FAILURE 3.0 Instructions (cont .. ) : 1 5.1 (cont) 5.1.3 Subsequent Action mem l 5.1.3.1 Comence Turbine Shutdown. See OP #0030125, Turbine Shutdown Full Load to Zero Load. 5.1.3.2 Commence Reactor Shutdown. See OP #0030128, Reactor Shutdown. 3.1.3.3 Commence Reactor Plant Cooldcun by dumping steam to the condenser manually using the steam dumps. See OP #0030127, Reactor Plant Cooldown Hot Standby to Cold Shutdown. 5.1.3.4 Implement the emergency plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator". 5 .1. 3 .5 Control Feedwater Flow to maintain steam generator no-load levels. /Rl: 5 .1. 3 .6 When RCS pressure is reduced to 900 psia: 5.1. 3. 6.1 Close the affected steam generators steam isolation valve. (HCV-08-1A or HCV-08-1B). . 5*.1. 3. 6. 2 Ensure that the steam isolation bypass valve (MV-08-1A or MV-08-13) is closed. . 5.*l. 3. 6. 3 Isolate feedwater to the affected steam generator.
~
5.1.3.7 Continue reactor cooldown to a cold shutdown conditbn using the unaffected steam generator. 5.1.3.8 Sample the condensate system to determine activity levels. 5.1. 3.9 Take air particulate and air gaseous samples in the following areas: 5.1.3.9.1 Air ejector after condenser and gland steam condenser combined vent. 5.1. 3. 9. 2 Steam driven auxiliary feed pump exhaust. 5.1.3.10 Conduct radiation sur a.y and post radiation areas as necessary. . t 1 i k
-l
Pags 5 of 15 EMERGENCY OPERATING PROCEDURE 0120041 REV.12 STEAM GENERATOR TU3E LEAK / FAILURE 3.0 Instructions (Cont'd) 5.2 Tube Failure (Exceeds Capacity of Charging Pumps) 5.2.1 Immediate Automatic Action:
,,j 5.2.1.1 A Steam Generator blowdown monitor alarm will actuate a high radiation alarm in control and signals to trip closed the blowdown and sample valves.
5.2.1.2 Reactor trip if pressurizer pressure decreases to the TM/LP setpoint. 5.2.1.3 Initiation of safety injection if pressurizer pressure decreases to 1600 PSIA. 5.2.1.3.1 Initiation of SiAS will cause CIS actuation. 5.2.1.4 Letdown control valves close to a minimum value, the backup charging pumps are started as pressu-rizer level decreases. 5,3.1.5 Pressurizer low low level alarms, and pressuri2er heaters deenergiz,e. 5.2.1.6 Turbine Trip (if reactor trips) NOTE: If turbine trip occurs the Main Feed
~
Regulating valves will close and the 15% Sypass Valves will open to 5% flow position. ~ 5.2.2 Immediate Operator Action: 5.2.2.1 Place additional charging pumps in operation, if not operating. t 5.2.2.2 Notify dispatcher and reduce turbine lead in prepara-tion for reactor shutdown. 5.2.2.3 Determine affected steam generator by: 5.2.2.3.1 Comparing steam generator levels. 5.2.2.3.2 Comparing steam generat.ars feed flow and steam flow. 5.2.2.3.3 Comparing steam generator blowdown monitors. I'
/,
Paga 6 of 15 l EMERGENCY OPERATING PROCEDURE 0120041, REV.12 STEAM GENERATOR TURE LEAK / FAILURE
5.0 Instructions
(Cont) i i I 5.2 (Cont'd) ,
, ,f,
,,y I ', ,
~
5.2.2 (Cont'd) {' - 5.2.2.4 Take manual control of atmospaeric dump valve ' controllers HIC 08-2A and HIC 108-23 and close them. 5.2.2.5 Check condenser air ejector vent aligned to the plant vent. ,'
/
5.2.2.6 Insure the reactor trips when pressurizer pressure decreases to IM/LP setpoint. 5.2.2.7 Carry out Lamediate operator action for reactor trip per OP 0030130. s 5.2.2,8 After an SIAS caused by low reactor coolant system pressure and after it has been verified that all CEA's have been fully inserted.for 5 seconds, stop all operating react.or coolant' pumps. , 5.2.2.9 Ensure safety injection an'd containment isolation actuation signals have occurred or initiate manually. /. Ensure HPSI flow to the core when pressure decreases ' below the pump's shut-off head ( 1250 psia). 5.2.3 Subsequent Action '" 5.2.3.1 Refer to Table I to ensure the proper operation of engineered safety features as tise ard condi-tions permit. 5.2.3.2 control feedwater flow to maintain Stean ' Generator no-load levels, s 5.2.3.2.1 If safety injection actuation has occurred the auxiliary feedwater system must be used to control the non-affected steam generator, level. When establishing auxiliary feed flow c to the steam generator, use steam generator levels as well as header flow rates to ensure each steac
. generator is receiving auxiliary feedwater.
k l /
/t t
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R Page 7 ofl5 EMERGCICY OPERATING PROCEDURE 0120041, REV. 12 l STEAM GENERATOR TUBE LEAK /FAII.L"AE
5.0 Instructions
(Cont'd) 5.2 (Cont'd) 5.2.3 Subsequent Action (Cont'd) 5.2.3.2 (Cont'd) . NOTE: If possible, the electric driven auxiliary feedwater pumps should be used; however, if the steam dr1ven pump is used, ensure steam supply is selected to the non-affected steam generator. 5.2.3.3 Ensure that HPSI pumps and charging pumps restora pressurizer level and pressure. NOTE: Pressurizer pressure will stabilize at approxi=ately 1175 PSIA and level at aoproxiestely 10%. Laplenent with the emerge ncy plan as necessary in accordance ". EPIP.3100021E.
- Dut.es.of the Emergency Coordinator 5.2.3. 4 Restore ICW to TCW Heat Exchangers by opening //
MV-21-2 and M'l-21-3s 5.2.3. 5 Stop emergency diesels if off site power is
. available.
- 5.2.3. 6 Close condenser hoewell reject valve, LCV 12-5.
s i 5.2.3.7 Commence RCS cooldown using SBCS if available. If the SBCS is unavailable, use steam dump to atmosphere on the non faulted steam generator. 5.2.3.8 Stabilize RCS cold leg temperature at 505CF. NOTE: This temperature will ensure adequate NPSH for four pump operation with RCS pressure at 900 PSIA. 5.2.3.9 When pressurizer level increases above 30%, energize pressurizer heaters. 5.3.2.10 De-pressurize RCS to 900 PSIA using pressurizer sprays. Throttle HPSI pumps discharge valves as required to maintain pressurizer level approximately 35%. 5.2.3.11 When RCS pressure is 900 PSIA, isolate the . affected steam generator by closing its MSIV and bypass valve. , l A
\
f
. I s . .
Pags 8 of 15 I EMERGENCY OPERATING PROCEDURE 0120041, REV. 12 ; STEAM GENERATOR TUBE LEAK /FAII,URE ! l
5.0 Instructions
(Cont) W 3.2 (Cent) *
. 5.2.3 Subsequent Action (Cont) 5.2.3. 12 Ensure feedwater is isolated to the affected steam generator.
5.2.3. 13 To allow potential ECCS area radioactive leakage and RCS sample water, collected in the ECCS area sumps to be pumped to the Reactor Coolant Drain Tank inside containment, perform the following:
- 1. At the C.R.A.C. panel place the "ECCS Area Leakage System" control switch to the "RDT" position and ensure that:
HCV-06-9 "R.D. Pump Suction" closes HCV-06-7 " Sump Pump to EDT" closes HCV-06-8 " Sump Pump to RDI" opens
- 2. At RTGB 105 open A0V-6301 and A0V-6302 "RDT Contmc Isol" valves by placing the~ switches in reset, then open positons.
, 3. Ensure the C.R.A.C. panel annunciator "ECCS '
Pump Room Lsakage Valves Misa11gned" is not lit. NOTE: The following valves are provided with "CIS-0VERRIDE" capability: A0V-5200, 5203 " Reactor Coolant Sample" FCV-26-1, 3 " Containment Sample Supply" FCV-26-2, 4 " Containment Sample Return" A0V-6301, 6302 "RDT Containment Isolation" 5.2.3.14 Re-commence RCS cooldown using the non-affected steam generator. NOTE: Do not exceed 750 F cooldown in any one hour. 5.2.3.15 Block MSIS at 700 PSIA Steam Generator pressure. l O
Page 9 of 15 l EMERGCICY OPERATING PROCEDURE 0120041. RE7. 12 STEN! GENERATOR TL'BE LEAK /FAILL*RE R/10 1
5.0 Instructions
(cont) , 5.2 (cont) ld 5.2.3 Subsequent Action (cont) 5.2.3.16 Establish and maintain 50 0F sub-cooling in the reactor coolant system. With the Subcooling Margin Monitor (SMM) operating normally, use the nomograph on RTG3 104 in conjunction with the SMM to eliminate dependence on a single instrument. With the SMN inoperable, refer to the nomograph utilizing control room indicators such as THOT, pressurizer pressure, and incore thermocouples to determine the margin to saturation. Sub-cooling margin can also be determined by subtracting hot leg temperature from pressurizer temperature (TE-1101). 5.2.3.17 Sample each steam generator for activity. 5.2.3.18 Sample the RCS to determine if there bae been fuel failure. 5.2.3.19 Sample the condensate system to determine , radioactivity levels. ,
.5.2.3.20 Take air' particulate and air gaseous samples in the area of the steam driven feed pump exhaust.
5.2.3.21 Conduct radiation surveys and post areas as required. A-
Page 10 of 15 EMERGENCY OPERATING PROCEDURE 01:0041, REV. 12 STEAM GENERATOR TUBE LEAK / FAILURE i 6.0
References:
num 6.1 Instruction Manual - Steam Generators, St. Lucie Unit No. 1 877-=5008. 6.2 EBASCO Prints 8770-G-079, 080. 6.3 Accident Analysis, FSAR, Section 15.4.4, Steam Generator Tube Failure. 7.0 Records Required: 7.1 Normal Log Entries. e +
- 9
- l
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EMERGENCY OPERATING PROCEDURE 0120041, REV 12 11 of 15 I i STEX( GENERATOR TU3E LEAK / FAILURE TA3LE I 1.0 Safety Injection ictuation Signal . I 1.1 Two HPSI Pumps ON [ ! 1.2 Two LPSI Pur.ns ON . ! 1.3 Eight HPSI Discharge Valves (HCV-3o17, 3627, i 3637. 3647) OPEN 1.4 Four LPSI Discharge Valves (HCV-3615, 3625, 3635, 3645) OPEN l . 1.5 Check proper operation of the Safety Injection System by the following means. 1.5.1 Check HPSI flow ratas on: FI-3311, 3321, 3331, 3341. 1.5.2 Check LPSI flow ratas on: FI-3312, 3322, , 3332, 3342. . . f 1.5.3 Check decreasing Safety Injection Tank ! Levels on: L1A-3311, 3321. 3331, 3341. 1.o Two CCW Pumos ON 1.7 Two CCW Valves from SDC HX's (HCV 14-3A, HCV 14-3B). OPEN 1.8 Four Containment Cooline Fens ON 1.9 Four CCW "N-Header" Isolatiou Valves (HCV-14-8A, 14-9, 14-8B. 14-10). SHUT 1.10 Four SIT Check Valve Lashoff Valves (V-Jb13, 3628, 3638. 3648). SHUT 1.11 Two R'. A.B. Main Supoly Fans (HVS-4A. 43) 0;I 1.12 Tuo ECCS %rea Exhaust Fans (HVE 9A, 93). ON* . 1.13 Eight Aux Bldg Dampers (D-5A, 6A, 9A, 12A, 5B, 63, 9B. 123)
- SHUT
- 1.14 ,Four Aux Bldg /ECCS Pump Room Dampers (D-13,14, 15, 16) OPEN 1.15 Four Reactor Coolant Pump CCW Isolation Valves (HCV-14-1 14-2. 14-6, 14-7). SHUT 1.16 Two FWP Discharge Valves (MV-09-1: MV-09-2) SHUT 1.17 Two Feedwater Block Valves (MV-09-7: MV-09-8) SHUT 1.18 Two Charging Pumps ON 1.19 Two Boric Acid Makeup Pumps ON 1.20 Two Letdown Isolation Valves (V-2515: V-2516) SHUT 1.21 VCT Qutlet Valve (V-2501) SHUT !
1.22 Two Gravity Feed Valves (V-2508; V-2509) OPEN 1.23 Emersency Borate Valve (MV-2514) OPEN 1.24 Two Sam Pump Recire Valves (V-2510, V-1511) SHUT 1.25 Blender outlet Valve to VCT (V-2512) SHUT 1.26 Load Control valve (MV-2525) SHUT I 1.27 Boric Acid Reader Discharge Valve (MV-2161) SHUT 1.28 Two Rx Cavity Sump Isol Valves (LCV 07-11A; LCV 07-11B) SHUT 1.29 Two Intake Cooling Water Pumps ON 1.30 Two ICW to TC7 Mx Isol Valves (MV-21-2; MV-21-3) SHUT 1.31 'A' ICW Lube Wtr. Supply to CW Pumps (FSU-21-3A) SHUT , 1.32 'B' ICW Lube Wtr. Supply to CW Pumps (FSU-21-3B) SHUT
- NOTE: Only one ECCS area exhaust fan is required, the other fan should be shutdown and kept in standby. ,
l I Page 12 of 15 i EMERGENCY OPERATING PROCEDURE 0120041, REV 12 STEAM GENERATOR TUBE LEAK / FAILURE TABLE 1 , 1 mm m 2.0 Containment Isolation Actuation Signal 2.1 Two Shield Bu11 dine Vent Faas UP!E-6A, EVE-6 3) ON* 2.2 Two Control Rocs Vent 2, coster Fans (HVE-13A. HVE-133) ON 2.3 Two Letdown Isolation Valves (V-2316, V2515) SHUT 2.4 Two RCS Samole Isolation Valves (V-5200. V-520 3-) SHUT 2.5 Four Pressuriser Sample Valves (V-5201, V-5202, V-5204, V-5205) SHUT 2.6 One Instrument Air To Containment Isolation Valve O!V-18-1) SHUT 2.7 Six Containment Purge Valves (FCV-25-1, 25-3, 25-5, 25-6, 25-4, 25-2) SHUT 2.3 Teo Centainnant Purte C::h2ust Fans ( HVE-8 A . hJE-8B) OFF 2.9 One Nitrogen to Containnent Sueolv Valve (V-6741) SHUT z.lu Two Contain= cut Waste Cas deader Isolation Valves (V-6554, V-6555) SFU"' 2.11 Two Containment Sump Pump Discharge Valves (LCV-07-11A, LCV-07-113) _ SHUT , 2.12 Four Steam Generator Blowdown Isolation Valves (FCV-23-3, FCV-23-5. FCV-23-4, FCV-23-6) . SHUT 2.13 Two Steam Generator Blowdown Sample Isolatioti Valves (FCV-23-7 and 9) SHUT 2.14 Two Reactor Drain Tank Discharge Isolation Valves (V-6301. V-6302) SHUT 2.15 Four Control Room Air Inlet Valves (FCV-25-16, FCV-25-17, FCV-25-14, FCV-25-15) SHUT 2.16 Two Control Room Kitchen Air Exhaust Valves (FCV-25-24, FCV-25-25) suuT 2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18, FCV-25-19) SHUT 2.18 Six Containment Radiation Sample Suetica and Return Valves (FCV-26-2. 4, 6. FCV-26-1. 3, 5) SHUT 2.19 Primary Makeup Water Isol Valve (MV-15-L) SHUT 2.20 Two RCP Controlled Bleedoff Isol Valves (V-2505 and ISE-01-1) SHUT -
- NOTE: Only one shield building vent fan is required, the other should be shutdown and kept in standby.
t L
i l l Page 13 of 15
. EMERGENCY OPERATING PROCEDURE 0120041, REV 12 STEAM GENERATOR TUBE LEAK / FAILURE TABLE 1 w .
3.0 Containment Snrav Actuation Signal 3.1 Two Containment Soray Pucos ON 3.2 Two Containment Spray Header Inlet Valves (FCV-07-1A, FCV-07-13) OPEN 3.3 Four liA0H (Caustic) Admission Valves (FSE-07-1A, FSE-07-2A, FSE-07-1B, FSE-07-23) OPEN 3.4 Verify Containment Spray Flow in FI-07-1A and F1-07-13. 3.5 Verify NA0H (Caustic) Flew on Post Accident Panel "A" TFI-07-2. FR-07-2) 0 . O t I
r l l Page 14 of 15 1 EMERGENCY OPERAT!!iG PROCEDURE 0120041, REV 12 STEAM GENERATOR TU3E LEAK /FAILL3E TABLE 1 l m 4.0 Recirculation Actuation Signal OFF 4.1 Two LPSI Punos 4.2 Two Saf ety Injection Min 1 flow Rectrc. Valves (V-3659, SHUT V-3660) OPCI 4.3 Two Containment Sur.o Outlet Valves (MV-07-2A MV-07-2B) Two L'r Outlet Valves (MV-07-1A, MV-07-1B) SHUT 4.4 4.5 Verify HPSI flow to core continues af ter RAS on F1-3321, FI-3341, FI-3311. FI-3331. O e . . O e t
Page 15 of 15,p EMERGENCY OPERATING PROCEDURE 0120041, REV 12 STEAM GENERATOR TUBE LEAK /?AILURE TABLE I 5.0 Main Steam Isolation Signal 5.1 Two Main Steam Isolation Valves (HCV-08-1 A, HCV-08-13) SHUT 5.2 Two Main Steam Isolation Bypass Valves (MV-08-1A, MV-08-13) SHUT 5.3 Two Main Feedwater Pump Discharge Valves (MV-09-1, SHUT MV-09-2) 5.4 Two Main Feedwater Block Valves (MV-09-7, MV-09-8) SHUT e 4 J ' e i
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I I Page 1 of 3 FLORDA ?C'4ER i LIGHT COMPANY ST. LUCIE PLANT UNI'" NO. 1 EMERGENCT OPERATING PROCCURE 0630040 RE7ISICN i t Y i'
1.0 Title
C3LORINE LEAK
2.0 Aooroval
Reviewed by Planc Nuclear Safety Commic:ee 1- F 19 ' * . Approved by </ N' / I. _ _ m . - 4, / Plant Manager "- >- 19 '* Revision l Reviewed by PNSC O 19 75 . Approved by ,- Plant Manager 19 . Revision 2 Reviewed by FRG _ [Mp 3O 19 7 7 Approved by ,1 /a/ N __.-j N ant Manager f. - r7 19 y f Revision 4 Reviewed by FRG fpb m A /O 19 R Approved oy_ .M_ M__ ___
///h,j Planc .".anager W/ s - 19A
3.0 Pucese
This procedure provides instrue:1ons to be followed in the event of a chlorine leak.. . . . .
~4.0 Svmocoms: -
4.1 Chlorine gas exhibi:3 a sharp pungent odor and causes irritation of
- he eyes, nose, throac and lungs. Laaks can be located by checking piping and connections with a rag dipped in at:monia vacer solution.
A white smoka vill forn when :he ammonia vapor conbines with the chlorine gas. 4.2 34facy Precautiens 4.2.1 Fersonnel not directly involved in :he E=ergency Laak Procedure should be evacuated from the area to an up-vind position. 4.2.2 Never use water on a chlorine leak. 4.2.3 Never immerse or :hrew a leaking cylinder into a body of water. FO R INF0lif.1 AT10N O N LY This document is not controlled. Before use, verify information with a controlled document. I' l
Page 2 of 3 CHLORINE LEAK l Emergency Operating Procedure 0630040 ; Revision No. 4
5.0 Instructions
5.1 Several one-ton chlorine cylinders are stored at the intake chlorinator and a single 150-pound cylinder is mounted next to the hydro-pneu=atic tank. Any large chlorine leak should easily be identified as coming from the chlorine bottle and """ manifold area or from the chlorine evaporation and dispens~er area. In either event, the areas are in close proximity to each other. 5.2 At the first indication of a gas leak, all personnel should be notified to remove themselves from the affected area to a place upwind from the leak. 5.3 Notify the Plant Supervisor or Watch Engineer immediately. Activate First Aid and Personnel Decontamination Team if R4 injuries are involved and the fire team to perform leak location and personnel rescue. 5.4 Using a self-contained air breathing apparatus, remove anyone who has been overcome by chlorine gas. Ce==ence First Aid immediately. 5.5 Implement the Emergency Plan as necessary in accordance with R4 EPIP 310002,lE, " Duties of the , Emergency Coordinator". 5.6 Locatt the source of the leak and isolate it. If leak is down-stream of container isolation valve or due to faulty operation of chlorine evalorator with resulting liquid chlorine carry over into chlorine dispenser, then close chlorine bottle valve and place chlorine eductors in service. This should evacuate the chlorine from the system, 5.7 If a leak in a container cannot be stopped, turn leaking cylinder so that gas rather than liquid will escape. Remove as much gas as possible to reduce pressure in the cylinder. NOTE: Water should not be sprayed on a chlorine leak to reduce the amount of chlorine gas or liquid leakage. The application of water makes chlorine much more corrosive and only increases the leak. Water may also warm the chlorine, thus increasing the pressure and force the chlorine to escape faster. A gas leak is only 1/15 of a 11guld leak. 5.8 Obtain leak repair kit, one for 150-lb. cylinder and one for one-con cylinder located in Fire House en painted wall bracket. These kits can repair any leak short of a major rupture. - I 1 I I
f i
.k Page 3 of 3 j' I i il b
CHLORINE LEAK Emergency Operating Procedure 0630040 Revision No. i 5.0 Instructions, Continued ham 5.9 Never use water on a leak and never ic=erse a leaking R4 cylinder in water or other solution. 5.10 If leak cannot be repaired with emergency kits, set up an R4 absorption tank containing a caustic soda or soda ash solu-tion and allow the cylinder to discharge through the solu-tion using a hose. ABSORPTION TANK CAUSTIC SOLUTION 150 lb. cylinder - 188 lb. caustic (15 gal.) to 60 gal, water 2000 lb. cylinder - 2500 lb. caustic (196 gal.) to 800 gal, water 5.11 Contact Chemistry Department for assistance on caustic solution R4 and communication to supplier. 6.0 -
References:
6.1 Fisher Porter Co., Inst. Bulletin 70-9001 . 6.2 Turkey Point Information Bulle* tin " Chlorine" 6.3 Safe Handling of Chlorine Cylinders, The Chlorine Institute Inc. of New York 7.0 Records Required: 7.1 Normal log entries R2 I m-
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?sgo 1 of 5 FLORIOA ?OkB i *.!Gh":' COMP.WI ST. ' UCII UNIT 11 CIIRGIUCT OPERAT!UG PROCIOURE No. 0700040 RI?!SICN 10 1.0 li:le: <-
Loss of Feedwater or Steam Generator Lavel
2.0 Accreval
Reviewed by :he Facill:7 Raview Group 8'M Cb /1 197 7 Approved by J ,4/ /2 3.m ,- 4 , Plant Minager no# /0 19 7 <-~ Revision l'd 'Revieved by FRG /I70. e de i Z. 19 'J ' Approved by /@,.M// //ff m Plant Manager :r-/S - 193*t 3.0 Pureose and Discussion: 3.1 This procedure provides instructicas :o be followed in the event of loss of feedwater flow and/or loss of steam generator level. 3.2 '. css of steam generater level resul:s in e redue:1:n in ::p: bill:7 of :he secondar7 systa= to remove :he heat generated in the rese:or core. Loss of steam generator level results f cm :he inab111:7 to supply feedwater in an amount equal':o :he existing steam demand. Excessive staam demand, i.e., above feedwater ' system capability is . considered in F.=argency,0.P. 0810040, Main Steam Line 3reak. - 3.3 The loss of all feedwater to the steam generator and :he subsequent heacup of :he Reactor Coolant system will result in saturation conditions at high camperature and pressure in the Reactor Coolant System. This would cause a less of reac:or coolant = ass through the FORV's and code safeties and void formations throughout the system. A mv4-um effort should be directed toward he initiation of feedwater flow to the steam generators. Without feedwater, :he steam generators could boil. dry within approximately 13 sinutes. 3.4 The inability :o supply feedwater in :he required quanti:7 could result f cm one or a combination of the following: 3.4.1 Pipe break in :he condensate [feedvater system. 3.4.2 Flovpath blockage due :o valve closure or strainer stoppage. t l 3.4.3 Less of pumping capacity due to pump trip, loss of AC power, or pump cavi.ation. 3.4.4 Loss of C Anv414 =7 Feedvater pu=p remote op'~r'aEg-capability., ,,,,,,, , , , , _ , , , , , , , , , , 3.5 The following protective functions are provided :o prevent loss of heat sink. FOR INFORMATION ONLY[ TMs document is not contreHed. Before use, d nt. verity inleemati with a controlled ocume !
E I Paga 2 of 6 EERGENCY OPERATING PROCEDURE NO. 0700040, REV 10 LOSS OF FEEDWATER OR STEAM GENERATOR LEVEL 3.0 Purpose (cont) 3.5 (cont) 3.5.1 Reactor trip: 6 3.5.1.1 Steam generator low-low level at 39%. 3.5.2 Turbine Runback: 3.5.2.1 Loss of both heater drain pumps if turbine power is > 92".. 3.5.2.2 Loss of feedwater pump if turbine power is
> 60%.
3.5.3 Aux Feed Pump Auto-start at 34% steam generator level. 3.6 The action taken for loss of steam generator level is basically the same regardless of cause. That is, to trip the reactor, there-by removing the heat source, and restoring steam generator level with the su::iliar/ feed.: ster pu=ps. S is approach is due t: tha self-sufficient nature of the auxiliary feed system. It, in no way, depends on the normal feedwater system. The auxiliary feed system has the capability to bring the gnit to hot shutdown and remain there for a period in excess of 20 hours, r,egardless of any single failure in the normal feed system. Three auxiliary - feed pumps are 'available. Two notor driven pumps, either of which can sup' ply either steam generator and one steam driven pump which can supply either steam generator. The auxiliary feedwater system ties into each steam generator feed line downstream of the steam generator feed inlet check valve. Capability exists to feed either steam generator by any auxiliary feed pump. A break in the feed line between the feed line check valve and the steam generator would result in the loss of that steam generator as a heat sink. Corrective action would be to isolate feed flow to that steam generator and continue maintaining level in the unaffected steam generator. Rasidual heat cr.n be adequately dissipated in this manner. The leak must be isolated in any incident involving a break even though the break does not immediately affect the auxiliary feedwater system. The isolation of a leak is necessary to conserve the water available'in the condensate storage tank. The leak is isolated by stopping the steam generator feed pumps and condensate pumps. A leak downstream of a steam generator feed line check valve would also require stopping auxiliary feed flow to that steam generator. l L _
Page 3 of 6 l DiERGENCY OPERATING PROCEDURE NO. 0700040, REV 10
~
LOSS OF FEEDWATER OR STEMi GENERATOR LEVEL 3.0 Purcose (cont) 3.7 The Aux feed pumps will auto start approximately 3 minutes jy following either S/G 1evel dropping below .34* (2/4 logic). Flow is automatically initiated to both steam generators and cannot be terminated for 30 seconds. Bypass switches are provided on RTGB 102 which will prevent pump starts and valve stroke and would be utilized if normal feedwater flow remains or becomes available and is desired.
4.0 Symptoms
4.1 Low-low steam generator level. 4.2 Low feed pump suction or discharge pressure.
~
R/9 4.3 Steam generator feed pump trip. 4.4 Condensate pump crip. 4.5 Heater drain pump trip. 4.6 Increasing Tavg. G g I
Pags 4 of 6 EMERGENCY OPERATING PROCEDURE NO. 0700040, REV 10 LOSS OF FEEDWATER OR STEAM GOTERATOR LEVEL
5.0 Instructions
5.1 Immediate Automatic Actions (some or all of the following may ? occur.) L 5.1.1 Reactor trip. 5.1.2 Turbine trip. 5.1.3 Transfer from Auxiliary transformer to startup transformer of auxiliary power. 5.1.4 Generator OC3's open. 5.1.5 Steam dump to condenser actuation. 5.1.6 Atmospheric dump actuation. 5.1.7 Steam generator relief activation. 5.1.8 With a turbine trip, the main feed reg valves will close and the 15% bypass valves will open to = 5% flow position. 5.1.9 Aux Feed Pump auto start sequence at 34% indicated level. 5.2 Immediate Operator Action. 5.2.1 With reactor trip. , . 5.2.1.1 Carry out inmediate operator actions for reactor trip per OP 0030130. 5.2.1.2 If one feed pump is lost, feed steam generators with remaining feedwatar train. 5.2.1.3 If both feed pumps are lost, immediately initiate auxiliary feed to the steam generators. Stop both heater drain pumps and leave one condensate pump running to cool down the secondary systems. When establishing auxiliary feed flow to the steam generators, use steam generator levels as well as header flow races to ensure each steam generator is receiving auxiliary feedwater. NOTE: If C Auxiliary Feedwater pumps is the only remaining means of adding feedwater to the steam generators and Control Room operation cannot be established, manually operate C Auxiliary Feedwater pump in accordance with Step 5.3.1.3. 5.2.1.4 If a major ~ rupture occurs in the condensate-feedwater system immediately trip both condensate
- pumps, both heater drain pumps, and both feed pumps to minimi
- e damage to secondary components.
I Lamediately initiate auxiliary feed flow to the steam generators. (Isolate rupture as quickly as possible.) L
Pagn 3 of 6 b EMERGENCY OPE?ATING PROCEDURE NO. 0700040. REV. 10 LOSS OF FEEDWATER CR STE.$M GENERATOR LEVEL
5.0 Instructions
(Cont'd) 5.2 I= mediate Operator Action (Cont'd) 5.2.1 Witn reactor trip (Cont'd) i ' d had i 5.2.1.5 Refer to applicable Subsequent Actions. 5.2.2 I=cediate Operator Action (Reactor does not trip) 5.2.2.1 If loss of a feed pump results in a turbine runback, check that: l 3.2.2.1.1 The load reduction is consistent with the capacity of the operating feed pump. 5.2.2.1.2 Steam generator levels can be maintained using one feed pump. 5.2.2.1.3 Reactor pcwer is matched with turbine power (Tavy = Tref) 3.2.2.2 Refer to applicable Subsequent Actions. 5.3 Subsequent Actions , 5.3.1 Subsequen,t Actions (with reactor trip) 5.3.1.1 Implement the Emergency Plan as necessary in R10 accordance with EPIP 3100021E, " Duties of the E=ergency Coordinator". 5.3.1.2 Monitor auxiliary feedwater flow to each steam generator. If either steam generator cannot be maintained above 38: with auxiliary feedflow and its pressure is relatively low compared to the other steam generator, secure auxiliary feed flow to this steam generator. 5.3.1.3 If all main feedwater flow is lost, coordinate the dumping of steam and the addition of aux 11-iary feedwater to restore steam generator level to approximately 65% and Tavg to approximately 532 F. NOTE: Use caution to avoid excessive cooldown on addition of auxiliary feedwater. If steam generator level is 38% or less, do not feed at greater than 785 gpm (flowrate of 2 motor driven or 1 steam driven auxiliary feedwater pu=ps feeding one steam generator). I L L
Pago 6 of 6 CERGEICY OPERATING PROCEDURE NO. 0700040, REV 10 LOSS OF FEEDWATER CR STEA21 GETERATOR LEVEL 5.3 Subsequent Actions (cont'd.) 5.3.1 Subsequent Actions (with reactor trip) (cont'd.) 5.3.1.4 If manual operation of C Auxiliary Feedwater pump is necessar-{, proceed as follows: , 5.3.1.4.1 Establish communications between the Control Room and the Auxiliary Feedwater S ta tion. 5.3.1.4.2 Open breakers 60308 and 60310 at 125 V. DC Bus 1AB. This removes power from trip and throttle valve MV-08-3. NOTE: With these breakers open RPM indication is lost.
- 5. 3.1.4 . 3 open MV-08-13 or MV-08-14, Main Steam Supply to C Auxiliary Feedwater pump.
5 . 3.1.4 . 4 Take manual control of trip and throttle valve MV-08-3 and slowly open it. Throttle this valve to raise C Auxiliary Feedwater pump discharge pressure to approximately
- 1200 psig. ,
5.3.1,4.5 Feed the Steam Generators by opening
, MV-09-11 and MV-09-12. Adjust turbine ,
speed with MV-08-3 to regulate feed flow. 5.3.2 Subsequent Actions (without reactor trip) 5.3.2.1 Af ter insuring the plant is in a stable condition, determine and correct the cause of the loss of feedwater. 6.0
References:
6.1 FSAR, Section 15.2.8, and Section 10.5.3. 6.2 Combustion Engineering Emergency Procedure, F-EP-9. 7.0 Records. Reports and Notifications: 7.1 Log Book entries. L C}}