ML18043A685
| ML18043A685 | |
| Person / Time | |
|---|---|
| Site: | Millstone, Palisades, Saint Lucie, Arkansas Nuclear, Maine Yankee, Fort Calhoun  |
| Issue date: | 05/09/1979 |
| From: | Thadani A Office of Nuclear Reactor Regulation |
| To: | Ross D Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML18043A686 | List: |
| References | |
| TASK-07-03, TASK-7-3, TASK-RR NUDOCS 7905230087 | |
| Download: ML18043A685 (90) | |
Text
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UNITED STATE&
NUCLEAR REGULATORY COMMISSiON.
WASHINGTON~ 0. C. 20555 MAY
- 9. 1379 MEMORANDUM FOR:
D. F. Ross, Jr., Deputy Director, Division of Project Manageme'nt, NRR FROM:
A. C. Thadani, Reactor Systems Branch, DSS, NRR
SUBJECT:
SUMMARY
OF MEETING WITHC-E REGARDING NATURAL CIRCULATION CONDITIONS, MAY 1, 1979
. :Enclosed are the minutes of the May 1, 1979 meeting between the staff and Combustion Engiheering on natural circulat1on conditions.
- .The meeting was also attended by most of the C-E. designed plant owners.
The *attendance list *is provided in ~he enclosure. ;
Enclosures:
1~. Attendance List 2 ~-
Slides:
Response to.LOFW Events 3~~ Slides:
Small Breaks
- 4. Slides:. Control Systems
- s~ :Slides: Additional Information
- 6. Slides:
. cc:
(S~e Attached Li*st)
Contact:
Ashok Thadani, NRR 49-27341' i.
l/tc/'~1J6N~..
Ashok C. Thadani
- Reactor Systems* Branch.
Division of Systerns Safety
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R. Mattson R. Tedesco T. Novak
- s. Hanauer J. P. Knight D. Skovholt o~ Vassallo w~ Gammi 11 R. Vollmer B. Grimes I
J. R. Mi l.l er *
- w. Kreger!
- v. Moore*'
M. Ernst R. Denise L. Crocker IE (3)
-NRC. PDR Local PDR*
- *If docketed
- o. -Bunch E. case H. Denton
'.R. Scholl
'l. Riani J. Wermiel I. Vi 11 a lva
- _A.* Schwencer
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- Rei 11 Y P.-Matthews D.. Ross J. S_hapakar I
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+Meeting Attendees:
R. S1iver (2)
G. Vissing (2):
- M. Conner (2) *
._ P. Erickson '(2)
- c. Nel_son (2)
Mr. James H. Taylor Manag~r, Licensing Babcock & Wilcox
_P.o;~~ox 1260
- ! Lynchburg, VA 24505 Mr. Larry Gifford _
Gen~ral Electric Company
- 4720 Montgomery Lane Suite 1107 *
- Bethesda, MD 20014
-i Dr. Glenn G. Sherwood, Manager Safety & Licensing i,*
General Electdc Company 1
- 175 Curtner Av~nue. * *
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San Jose, CA 95125 7 9.0-5 2 3 0 0 8 7 Mr. Raymond R. Mills, Jr.*
Project & Generic Licensing Supervisor Combustion Engineering, Inc~
1000 Prospect Hi 11 Road i' *. Windsor, CN:
06095 *
- Mr~ Thomas Ander~on,.Manager Nuclear Safety Department
\\i - Westinghouse ElectriC Corporation Box 355 Pittsburgh; PA 15230 I
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. (Please return 1pink copy+ 3. ex.tras to C. Jamerson, P-1132)
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-.,..o,5.q.-;cr RETURN TO R,&\\CTOR DOCKET
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ENCLOSURE mevnO -m Ross
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SUMMARY
OF MEETING WITH C-E REGARDING NATURAL CIRCULATION CONDITIONS, MAY 1, 1979 On May 1, 1979 the NRC staff met with representatives of Combustion Engineering (C-E) Corporation in Bethesda, Maryland, to discuss several considerations related to natural circulation in C-E operating reactors.
Representatives of Baltimore Gas and Electric, Arkansas Power and Light, Northeast Utilities, Florida Power and Light, Yankee Atomic Electric, Omaha Public Power, and Bechtel were also present. A list of attendees is attached (Enclosure 1).
The meeting opened with the presentation of the proposed agenda.
The following seven areas were discussed:
- 1.
C-E systems response to LOFW events,
- 2.
Small break LOCAs and the response of C-E systems,
- 3.
Control systems impact on protection systems,
- 4.
Additional information on natural circulation and the design of core exit thermocouples,
- 5.
Thermal shocks,
- 6.
Power-operated re 1 i ef v_a 1 ves,
- 7.
ECCS and auxiliary feed actuation.
- 1.
Response to LOFW Events (See Enclosure 2)
First, C-E reviewed their understanding of the major components of the event at TMI-2 which included complete loss of feedwater, -open~ng cif. the pressurizer PORV, short delay in initiation of auxiliary feedwater, termi_n*ation of HPSI and RCP flow, and delayed containment isolation.
A.
How would C-E operating plants respond to a loss of feedwater event?
.C-E explained that the following would occur on loss of feedwater:
1~ S.G. level would decrease,
- 2.
RCS pressure would increase slowly,
- 3.
Reduction in S.G. heat transfer,
- 4.
At 15-20 seconds a reactor trip on S.G. low level,
- 5.
No automatic trip of turbine on LOF.
- 6.
A combination of steam dump and turbine bypass valves would open in conjunction with the pressurizer control system to regulate the RCS pressure to a hot standby condition,
- 7.
The PORV does not open.
7 9 O 5 2 3 O 0 9 8 C-E stated the control systems are not on vital buses and that there is at least a 10-minute grace period before the auxiliary feedwater
- system must be manually initiated to prevent large degradation of S.G.
heat transfer capability.
Even if the tubes. are aJmost all uncovere_d, c~E indicates that decay heat can still be removed. - *
- ~
B.
Effect of a.Stuck Open PORV C-E indicated that the following events would occur should a PORV.
open and stay open.
- 1.
Rapid depressurization of RCS,
- 2.
If no other reactor trip occurs prior, reactor trips on low pressurizer pressure (5 to 10 seconds)~
- 3.
ECCS actuates at 1600 psig,
- 4. There is flashing in RCS which causes insurge into the pressurizer,
- 5.
The pressurizer fills and a 2-phase mixture is relieved through the PORV,
- 6.
Pressurizer drain tank ruptures and fluid is released to containment,
- 7.
Operator terminates event by closing PORV block valve.
C-E stated that the PORV has about one half the area of a safety valve.
C.
C-E Mitigating Design Features The following information on C-E system design was given by the C~E representatives in discussions with the staff.
C-E's analyses presented on May 1, 1979, did not address the effect of shutting off the HPSI pumps after they were once started since C-E recommends maintaining the pumps on during all critical periods of an event and beyond and also b~cause prolonged loss of HPSI would eventually dry out the primary system for events which remove primary inventory.
At it normal operating level, a C-E steam generator has approximately t*wa full power minutes of inventory and has slight}y more than one full power minute at the steam generator low level limit. If the event begins with a normal S.G. level and the reactor trips at the low level limit, sufficient inventory exists t~ remove stored and de~ay.he~t fo~
13 minutes (10 min. for AN0-2).
If instead the reactor trip is immediate, about 40 minutes of inventory would be available. Auxiliary feedwater must be provided* to remove additional decay heat.
C-E indicated that these times are from Chapter 15-type analysis.
The analyses presented by C-E assumed that control systems are in automatic.
If the systems are in manual, the PORV can be challenged.
By design, if you have control systems in the automatic mode, you will not challenge the PORV, but you will dry out the S.G. faster.
The HPS~ pump~ will not lift the safeties or the PORV.
The.NSSS layout (ele~at1ons)_ is such that only 2Q-25 percent of RCS inventory is required to cover the core. The ECOS is usually initiated on either low pressurizer pressure or high containment pressure.
Pressurizer level does not initiate automatic safety systems.
C-E said some.
plants may not initiate on. high containment pressure. There are no loop seals in the pressurizer surge lines.
However, from the suction of the RCP to the steam generator there is a loop seal.
C-E interface requirements state that pressurizer surge line elevation must increase monotonically from where the line exits the hot leg.
On one operating C-E plant the pressurizer surge line comes out of the side of the hot leg.
All others enter at the top.
- 2.
Small Breaks (See Enclosure 3)
C-E discussed the system response of the C-E operating plants to small break LOCAs.
The following discussion outlines the comments made by Combustion Engineering.
Should a small break occur at the top of the pressurizer, rather than at the cold leg pump. suction, the PCT would be 2QQOf cool~r. Using a 100 percent ANS curve rather than a 120 percent ANS curve :gives a 500°F PCT drop for the worst small break.
No real worrie~ of boron precipitation affecting natural circulation for small breaks.
The highest PCT for a small break analysis on an operating C-E plant is about 19QQOf.
Cold leg breaks are worst.
For System 80, the elevation difference between the top of the active core and the bottom of the S.G. tube sheets is 14 f~et. There is no significant difference in ope~ating plant elevations (!2 feet).
As long as a C-E plant has secondary water, C-E does not expect bubbles to form early in the primary side of their S.G. since the reactor coolant enters at the bottom of the U-tubes and is immediately cooled.
During depressurization, the first bubble should form in the reactor vessel and latter in the steam generator after the hot legs uncover.
A moderate volume of noncondensables in the U-tubes of the S.G. does not cause catastrophic loss of the heat sink.
The secondary system for a small LOCA will ride on the S.G. safety settings.
The primary system wil.l be about 50 psi higher.
Should noncondensables block the top of the S.G.
. tl!bes, the RV side of the S.G. will undergo condensation heat transfer~
If the noncondensable bubble is 260 ft3,.would still have 46 percent of heat transfer area in S.G.
available~ A smaller bubble.would not block the tubes or greatly restrict heat transfer.
Nitrogen from the SITs would only be dumped for large breaks and even then not all of the N2.
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'I If the area of a small break is equal to or smaller than.02 ft2, calculations predict no core uncovery if secondary cooling is available.
For O. 05 ft2
- break using 100 percent ANS decay heat ther~ is no core uncovery.
If there was no S.G. heat transfer, the amount of noncondensables released would !double or triple.
I The! a;ea of a safety valve is about.03 ft2 and the area of a PORV is about
- 01 ft2.
Should a safety valve stick-open,. no core uncovery is predicted and PCT would be governed by DNB.
NOTE:* Primary system and secondary system depressuri zation is attained using nonsafety-grade equipment.
In the report 11 Decay Heat Removal Problem Associated with Recovery from a Very Small Break LOCA for C-.E 1System 80 PWR 11 by C. Michelson (hereafter called 11the Michelson report 11
) Michelson said for some breaks (mode 5) slug flow would impact the steam generator tubes.
C-E feels that this problem would have minimum effect on steam generator structural integrity.
C-E calculations predict 100 pounds mass steam per second boil-off at 1200 ~~conds for a 0.02 ft2 break.
Steam velcicities would approach 10 feet
~er second in the hot leg and 5 feet per second in the steam gert~rator tubes.
For small breaks H2 release due to core oxidation is minimal and has little or nb effect on natural circulation.
'In' order to model nonconden~~bles in the core and steam generator during a small break lOCA, S.G; he~t transfer values were made arbitrarily low.
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In the Michelson report noncondensables build up in the steam generator and block natural circul.atioh flow.
C-E has calculated (via CEFLASH-4AS) that a 9 psi increase in the core is sufficient to sweep out the gas in steam generators.
t-E feels that most of noncondensables will be trapped in the upper head of the rea~tor ve~sel.
From the control room, you can tell if you have natural circulation (approx.
2 percent of norinal flow) by reading loop l:ITs and secondary heat transfer, I
For breaks of.005 ft2 and larger, you can use the recirculat~on decay heat removal mode of cooling: For breaks gr~ater than.02 ft you must use the recirculation mode.
Reflux heat transfer is modeled into the CEFLASH (1st hour) and CELDA (after 1st hour) codes whith were used in combination to ~alcul~te small breaks
- out to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.
No secondary side failures were assumed in the small break analyses.
Only one auxiliary feedwater pump is required to meet decay heat removal demands after a short period. Auxiliary feedwater fl ow is about I
r perc0.nt of full power feedwater flow.
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,:. If a bubble were to form in the core and if it expanded down towards the cqre, it would first uncover the hot legs where the bubble would then be swept out. *From the hot leg to the top of the active core there is more thari 300 ft3 of water which the bubble cannot remove as long as HPS1 is
~v~i~cible and the S.G.'s act as a heat sink.
(-E~ has res'ponded to utility questions regarding recent NRC bu1letirls on turnirig off HPSI pumps following an event.* C-E intends to provide additional detailed 'information to the utilities in about 1 month.
For breaks 1from.01 to.005 ft2, the analyzed small breaks depend on S.G.2 reflux heat transfer and steam generator heat sink.
C-E discyssed.03 ft break *from lbeginning to end. *This :i~ shown in Enclosure 3 in some detail.*
- 3. ' Control Systems (See Enclosure 4)
C-E discussed the contro-1 systems they supply to utilities with their NSSS* design.
Control sensors are'. separate from safety system sensors.
. There are master control stations where more. than one valve can be positioned by one switch.
See Enclosure 4 for a list of all control systems.
Control systems use redundant 2/2 logic to enhance safety and availability by preventing single control system failures from causing sttOng, ~apid control system act~6ns.
In 28 reactor years of opetation, C-E plants, to the.best of C-E's kn,owledge (NRC must pursue asa fornialsurvey), there.have been*six a~iomatic strams on C-E ~1ants due to NSSS to~trol system sensor or logic*
failures out of abo~t 125 total scra~s.
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. To C-1E's knowledge there have been nd pressurizer spray valve failures**
in operati,ng c..;E plants which challenged t.he safety systems~
No credit.
isi taken for pressurizer heaters in either loss of offsite power or* sniall.
1break LOCAs.
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- 4.
- Additional Information (See Enclosure 5)
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- 1.
- 2.
. *3,
- 4.
- 5.
- 6.
- 7.
- 8.
R_eactor trips, RCPs coast down.
I T:urbine trips,..
Condenser lOst, Mai n FW 1 o st, :
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. Assume Auxiliary FW not initiated, No charging/letdown, No heaters/spray, No wall heat transfer.
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No wall heat transfer ~aximizes pressure swings.
No charging/letdown and no heaters/spray may not be very realistic since most plants.can
~ut some pr~ssurizer heaters on emerg~ncy buses and al1 can put air
. compressors on emerge.ncy buses.
If a PORV is not opened when the S.G. pressure is maintained at 1000 psi, primary *system only goes 30 psi higher.
Plots in Enclosure 5 show primary system remains substantially sub-tooled after loss of offsite power (LOP).*
B.
Inadvertent Opening of Safety' Valves C-E presented plots of the inadvertent opening of a pressurizer safety valve (.03 ft2).
The core never uncover&.
Most of the energy is removed by the steam generators.
See fnclosure 5.
C.. : Thermocouples (See Enc'losure 5)
. C-E presented diagrams of the location and construction of their core *
- e*xit thermocouples.
A graph was *shown*wh:ich indicated that during a*
natural circulation test.where data were available, the thefmocbuples tracked the hot leg temperature in a rea?onable manner.
- The majorlty of C-E operating plants have thermocouples ~bout 18 ihches above the ci.ctive fuel.
The thermocouple data are processed by the plant computer and the displayed temperatures are limited to a range of about 550-6500F.
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- 5.
Thermal Shocks No data were presented on challenges to reactor vessel integrity.
Plots were provided (see Enclosure 5) for a 3-inch.thick pipe using conservative assumptions.
C-E indicated no crack growth was calculated down to ~bout 60°F.
- 6.
fORVs (See Enclosure 6)
C~E ~resented dat~ gather~d from various sriurces (utilitiesj gray b6ok~~
LERs; etc.) which though possibly incomplete:describe *PORV *actuations *
- to.date.
NRC must follow-up with a formal u_tility survey. *There have.
been four openings of PORVs in operating plants (including two inadvertently) with one failure to close (due to improper wiring).
The testing frequency of PORVs was que.stiohed by the staff. The *staff will check the.standard technical specificati~ns ~nd check with utilities on testing frequencies.
PORV.block valves are on vital buses.
C-E does not expect PORV actuation on load rejection events.
Some plan~s have up to 85. percent load rejection while o.thers have 20-30 percent..
- 7.
ECCS and Auxiliary Feedwater Actuation C-E presented data gathered from various sources (as were PORV data) which may be incomplete.
Emergency feedwater ha~/beftl\\\\ actuated a total of 17 times for LOF events, LOP events, and l oss~*of t"ondenser vacuum events.
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' C-E stated that an emergency feedwater system on a C-E operating plant has never failed to operate nor have there been any partial failures.
Emergency core cooling systems on C-E operating plants have been actuated nine times (three times inadvertently) with no failures to operate.
C-E knows of no cases where an ECCS was unavailable or had a partial failure.
- 8., Staff Questions to C-E I
- I A.
What can C-E or a utility do to reduce PORV challenges?
(For example, earlier scrams, increased PORV set point, reduced operating pressure with increased PORV set point or earlier scram)
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This calculation should be done realistically.
Indicate all negatives foreseen with staff suggestions or own suggestions.
What is steam generator inventory for C-E plants? What is*
low level set point inventory? Provide as lbm and as full power seconds of inventory.. Dry out times are also helpful.
- I'*
Provide ECCS set points in a matrix.
Have a column of generic -
assumptinns, a column of operating plant set points, and a
- column of remarks on t~e s i g'ni fi cance of differences to generic analysis.
List the *single failures assumed in ECCS analysis.
Parameter effects a~e tb be compared at the conditions of.05
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ft2.small break LOCA.
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Provide a matrix of scram signals fo+ operating plants.
NOTE:
Palisades does not have C-E fuel so information will be per last C-E analysis.
Maine Ycinkee also does own analysii.
See*
technical specifications.
Do plant emergency procedures following a small break LOCA or steam line break req~ire that the HPSI pumps be turned off to prevent overpressurizing the primary system?
- 9.
Staff Questions to Utilities with C-ENSSS
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.i l Describe the auxiliary feedwater systems.
What kind and number of pumps, pump flow ~ates, signals to actuate, pump maximum delivery, and discharge rates.
To be asked through DPM.
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ENCLOSURE 1 ;
Staff Meeting with c~E on Natural Circulation, May 1, 1979 Attendance List Name C. Graves S. Newberry G. Kelly L.B. Marsh A. Thadani W. Jensen C.R. Musick R. R, Mills C. L Kling RJC.L. Olson.
Jerry Mazetis Bruce Ritter Gerald J. Falibota*
Gary Quittschreiber Garry G. Young Rod Cook Ted Enos Richard Hart
- Joe Longo R. Schemel Leonard Ward 1
Carl Yoder, Jr.
R.E. Denton J.M. Callaghan R.S. Dalias T.C. Grozan D. K.. James R.C. Marshall Philip J. Guimond W. J. Paine James Brinkler T.R. Robbins S. Diab H.A. Wilber L.B. Engle Jack 1Guttmann F. Odar B. Clayton Affiliation NRC/DSS NRC/DSS NRC/DSS NRC/DOR NRC/DSS NRC/DSS C-E C-E C-E Baltimore Gas & Electric (BG&E)
NRC/DSS Bechtel Bechtel NRC/ACRS Arkansas Power & Light Co.
Arkansas.Power & Light Co.
Arkansas *power & Light Co.
Northeast Utilities C-E NRS/DSS C-E BG&E BG&E (Calvert Cliffs)
C-E C-E FP&L FP&L C-E Yankee Atomic Electric Co.*
Maine Yankee Maine Yankee Omaha Public Power Dist. (Pickard
.Lowe & Garrick)
- NRC/DOR NRC/IE NRC/DPM NRC/DSS NRC/DSS NRC/DPM (Part-time)
e I C-E OPERATING PLANT RESPONSE TO TMI TYPE SCENARIO
- MAJOR COMPONENTS OF TMI SCENARIO
- C-E OPERATING PLANT RESPONSE TO A COMPLETE LOSS OF FEEDWATER *.
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- C~E.OPERATING PLANT RESPONSE TO A STUCK PRESSURIZER POWER
. O~ERATED RELIEF VALVE <PORV)
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- C-E MITIGATING DESiGN FEATURES 2-. I
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MAJOR COMPONENTS OF TMI SCENARIO
- COMPLETE LOSS OF FEEDWATER
- PRESSURIZER PORV FAILS OPEN
- SHORT DELAY IN INITIATION OF AUXILIARY FEEDWATER I
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C-E OPERATING PLANT RESPONSE TO A COMPLETE LOSS OF FEEDWATER
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- TERi*HNATION OF FEEmtATER RESULTING Hi DECREASING STEAM G~NERATOR WATER.LEVEL
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- SLOW RCS PRESSURE RISE ti
- REACTOR TRIP ON LOW STEAM GENERATOR WATER LEVEL
- STEAM DUMP, BYPASS; AND PRESSURIZER CONTROL SYSTEMS REGULATE RCS.TO HOT STANDBY CONDITIOHS CPORV DOES NOT OPEN)
- AT LEAST 10 MINUTES AVAILABLE TO MANUALLY INITIATE AUXILIARY I i FEEDWATER BEFORE RCS PRESSURE RISES 11 I
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C-E OPERATING PLANT RESPONS.E TO A STUCK PRESSURIZER RELIEF VALVE
- .RAPID.DEPRESSURIZATION OF RCS
- TM/LP TRIP ON LOW THERMAL MARGIN
". ECCS INITIATION AT APPROXIMATELY 1600 PSIA
- FLASHING IN RCS RESOLTING IN PRESSURIZER INSURGE
- FILLING OF.* PRESSURIZER, RESULTING IN TWO-PHASE RELIEF THROUGH.
.
- FAILURE OF DRAIN TANK RUPTURE DISK AND FLUID RELEASE TO THE
. CONTAINMENT
.* OPERATOR CLOSES PRESSURIZER BLOCK VALVE TERMINATING
.* DEPRESSURIZATION I
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C-E MITIGATING DESIGN FEATURES
.. ~ ANTICIPATED RESPONSE TO 'MODERATE FREQUENCY EVENTS DOES NOT OPEN PORV
- . LARGE SECONDARY WATER INVENTORY ALLOWS SUFFICIENT TIME TO MANUALLY INITIATE AUXILIARY FEEDWATER
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- PRESSURIZER LEVEL IS NOT USED lO INITIATE AUTOMATIC SAFETY I
SYSTEM?
- LOW 1HPSI SHUTOFF HEAD WILL NOT' LIFT PRESSURIZER RELIEF OR:
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SAFETY VALVES
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- I. SMALL BREAK SPECTRUM s.GI,FEATURE.~,
SOURCES OF NON CONDENSIBLES ASSUMPTIONS VERY SMALL BREAKS I I. Sl1ALL BREAK SCENARIO I
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NOTE: PIPE ELEVATIONS GIVEN ARE FQR I.D. OF PIPES e
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HT TRANSFER TO SECONDARY OCCURS WITH ANY SECONDARY SIDE LEVEL MODERATE VOLUf*1E OF iJON-COimEr~SABLES DOES NOT CAUSE t.l\\TASTROFl'llC LOSS OF HEAT SINK
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CONTROL SYSTEM FAILURES THAT CAN CHALLENGE.PROTECTION SYSTEM IN OPERATIMG C-E PLANTS INTRODUCTION CONTROL SYSTEMS OVERVIEW OPERATIONAL HISTORY O~ C-E PLANTS C-E FEATURES TO MINIMIZE 1MPACT~OF-FAilURES
- ~..
TYPICAL CONTROL SYSTEM SCHEMATIC CDrJCLUSION.
I I.
I*
- ~~
e**-
- LIQUID
- INVENTORY CONTROL
. o PLCS
. PRESSURE CONTROL.
o PPCS MAJOR PLANT CONTROL SYSTEMS
. REACTOR* FOLLOWS* TURBINE. CONTROL MODE PRIMARY STDE*.
PLANT.LIMITS TAVG-CONTROL
- RRS 111BORON*
POWER DISTRIBUTION CONTROL
. DPLCEAs.
- FLCEAs
-~ BOP D.*NSSS*
PLANT LIMITS o *
- ANALOG. CONTROL iJ -:MANUAL.CONTROL SECONDARY
.SIDE
- .INVENTORY CONTROL
- FWCS PRESSURE CONTROL.
- SBCS
i I
MAJOR PL~NT CONTROL SYSTEMS LISTING
- PLCS ~ PRESSURIZER LEVEL CONTROL SYSTEM
,, PPCS - PRESSURIZER PRESSURE CONTROL SYSTEM RR~ - REACTOR REGULATI.NG SYSTEM
,1 I.
BORON - SOLUBLE BORON,CONCENTRATION CONTROL I
I PLCEAs :c. PART LE~JGTH CO'!TROL ELEMENT ASSEMBLIES FLCEAs - FULL LENGTH COMTROL ELEMENT ASSEMBLIES rCs - TURB !NE JoNTROL I SYSTEM.
I SBCS ~* STEAM BY~ASS CONTROL SYSTEM I
F\\1CS - FEEDWATER CONTROL SYSiEM
. \\
ii
+ -
, I I
I
'-{-3 I
- I. "e TYPICAL CONTROL SYSTEM SCOPE INCLUDED** ITEMS
- SENSORS*
E,XAMPLES:
RTDs,, DIP CELLS,, EX-:CORE DETECTORS
- SIGNAL CONVERTORS I
- 1 EXAMPLES:
- CURRENT-TO-:-VOLTAGE., CURRENT-TO-PRESSURE I
" I I
- CONTROL LQG IC I
. !'.EXAMPLES":*
LEAD/LAG.,; FILTER~
1
.GAIN,, H~TEGRATOR
,I 11 I
I I
- *OPERATOR INTERFACE *
. I
- i EXAMPLES*:*
M/A STATIOM,, IMflI'CATORS i'..
I'
- ACTUATORS
. EXAMPLES:
VALVE POSITIONERSI PUMP SPEED cotffROLS, CEDMs
- INTERCONNECTING WIRINGr.
~
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I C-E cmffROL SYSTEMS OVERVIEW 8 AUTOMATIC TURBH!E/REACTOR CO~*~TROL BETWEEN 15% AND 100% POWER EXCEPT FOR M.L\\NUAL CON-
.
- TROL OF BORON CONCENTRATION AND AXIAL POWER DISTIRBUTION I
0 CONTROL SYSTEMS LARGBLY SEPARATE FROM AND I
1, INDEPENDENT OF PROTECTIVE SYSTEMS I.,*
- REDUNDANT 212 LOG 1 c Jr~PLoYED To ENH.~NCE SAFETY
'I I
AND AVAIU\\BILITY BY ~REVENTING SINGLE co~~TROL.
SYSTEM FAILU~E~ FROM /CAUSING STRONG., RAPID CONTROL SYSTEM ACTIO~,~S i
STEAM, BXPAss coyRoL SYSTEM o CONTROL SYST~MS DESIJNED TO ENHANCE SAFETY AND AVAILABILITY,BY RESTqRING ACCEPTABLE COMDITIONS.
WITHOUT CHAL~ENGING T:HE PROTECTIVE SYSTEM DURING.
I A NUMBER OF DESIGN BASIS EVENTS
... I..
o EXTENSIVE DIAGNOSTIC/TEST FEATURES PROVIDED TO ENHANCE RE~IABI~ITY
, I I
I.
' 1 '.
~...
. '*.r*
I I
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I
, I I
I.
--~*** __
C-E CONTROL SYSTEMS OVERVIEW (cONTINUED)
- ALARr~1s PROVIDED TO IDENTIFY CONTROL SYSTEM FAILURES o AUTOMATIC OVERRIDES ON MANY FAILURES.
- MASTER CONTROL.STATIONS.TO MINIMIZE THE NUMBER
- OF OPERATOR ACTIDrJS DURING MANUAL CONTROL I
I
~
I
- FINAL CONTROL STATIO~~S. FOR EMERGENCY MANUAL
. CONTROL
- BACK-UP SENSORS AND LOGIC PROVIDED ON MAJOR.
CONTROL PARAM~TERS
AUTOMATIC SERAMS ON C-E PLANTS-DUE TO NSSS CONTROL SYSTEM SENSOR OR LOGIC FAILURES
TYPICAL FEATURES TO
\\
MINIMIZE 1
.
- AUTOM.L\\TI C CEA WITHDRAWAL PROHIBIT
.. HI CTAVG - TREF) HI Tc o CEA WITHDRAHAL PROHIBIT LOW THERMAL MARGIN HI NEUTRON FLUX POWER 1
~
- AUTOMATIC CEA MOTION INHIBIT. i
~ ~~~
(oY' J_;
NEUTRON FLUX POWER <15% 1.,.,...r ~ 1 a;t SELECTED. RRS IN TEST MODE ~
>,, ~'-;t;,,.l f
- ROD BLOCK CIRCUIT CEA BANKS OUT OF SEQUENCE
- DEMAND NO' CEA MOTION ON 'Loss OF POWER TO SYSTE~i
. *BUILT IN TEST PANELS FOR 'SYSTEM TEST AND STP.TUS INDICATION
e BLOCK DIAGRAM OF RCUC
/FIXED GAIN TAVG-Tr.:F ET COMPENSATION GAlN
=6. 9 piic /°F UNIT KT -
(LEAD - LAG)
I N[UTl~ON RODS FLUX OUT OUT (POWER)
I Es
+
T
~ SUMMER COMPENSATION
.GAIN ~
Ee J. ~~'
RODS
'-t:i UNIT
~ SUMMER I HCi.i:;
KB I
~
HOLD. 11
~
(DERIVATIVE) r~
(osio)
RODS TURBINE
.J
[N
~IN FIRST STAGE PRESSUR£:
0 (POWER 1 ~ JlJMPER Hl Hl REF)
H[ SPEED TI
~ 1 P~ESSU~IZER
'~
""' :O,\\~PENSATION Ep LO SPEED LO LO P~cSSU~E GAIN SUMMER:*;,
UNIT
~
f4 K
~*~
.* *.....,_{.
(DERIVATIV~}-*.:~:1 p
. ~ *.-
-;~ *.**; *,~.. -.*:
.~.. '.
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- . ~:-...
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- .~...,.
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- \\ ~..
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....c.
. I -
~
CONCLUSION NUMEROUS FEATURES INCORPORATED INTO NSSS CONTROL SYSTEMS ON OPERATING PLANTS HAVE HELD-THE NUMBER OF NSSS CONTROL SYSIEM SENSOR AMD LOGIC IMDUCED PROTECTIVE SYSTEM CHALLENGES DURH!G 28_ REACTOR ~YEARS OF OPERATION TO 6.
TH]S IS 3% OF ALL AUTOMATIC REACTOR TRIPS.
I Loss OF OFF-SITE Po~lER TIME = 0.0 REACTOR TRIPS TURBINE TRIPS RCPs COAST Do~IN MAIN CONDENSER 1s LosT
~~IN FEEDWATER 1s LosT AuxILIARY;FEEDWATER 1s Nor INITIATED I
PRESSURIZER ASSUMPTIONS No C HARG 1 NG/ LETDOWN 1 ~~";-<"'f-1,;, fu k,,_,, "!) 1/* f< ~
No HEAT-Rs/SPRAY j.t"vvJJi:%rl~1:cr,i::-~n-- ~
~
'f-1:
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- 1.
SECONDARY CODE SAFETY VALVESJ OR
- 2.
SECONDARY LLlMP VALVES
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