U.S. patent number RE30,589 [Application Number 05/971,991] was granted by the patent office on 1981-04-28 for method of effecting fast turbine valving for improvement of power system stability.
This patent grant is currently assigned to Fast Load Control Inc.. Invention is credited to Robert H. Park.
United States Patent |
RE30,589 |
Park |
April 28, 1981 |
Method of effecting fast turbine valving for improvement of power
system stability
Abstract
As a improved way of effecting fast valving of turbines of power
system steam-electric generating units for the purpose of improving
the stability of power transmission over transmission circuits to
which their generators make connection, when stability is
threatened by line faults and certain other stability endangering
events, the heretofore employed and/or advocated practice of
automatically closing intercept valves at fastest available closing
speed in response to a fast valving signal, and thereafter
automatically fully reopening them in a matter of seconds, is
modified by providing to reopen the valves only partially to and
thereafter retain them at a preset partially open position. For
best results the process of what can be termed sustained partial
reopening is so effected as to result in its completion within a
fraction of a second following the peak of the first forward swing
of the generator rotor. Control valves may be either held open, or
automatically fully or partly closed and thereafter fully opened in
a preprogrammed manner, or automatically moved to and thereafter
held in a partly closed position, by means of a preprogrammed
process of repositioning in which the valves may optionally be
first fully or partly closed and thereafter partly reopened.
Avoidance of discharge of steam through high pressure safety valves
can be had with use of suitably controlled power operated valves
that discharge steam to the condenser or to atmosphere. Where there
is an intermediate pressure turbine that is supplied with
superheated steam, use of sustained partial control valve closure,
if employed, is supplemented by provision .Iadd.for reduction of
.Iaddend.rate of heat release within the steam generator in order
to protect the reheater from overheating. .Iadd. As a way to
restrict increase of reheat pressure of fossil fuel installations,
and to minimize increase in the MSR (moisture separator-reheater)
pressure of nuclear units, provision is optionally made of normally
closed by-pass valves which are arranged to accept reheat or MSR
pressure steam and discharge to the condenser in response to either
an an increase of reheat or MSR pressure that takes place other
than slowly, or to a fast valving signal, or both. .Iaddend.
Inventors: |
Park; Robert H. (Brewster,
MA) |
Assignee: |
Fast Load Control Inc.
(Freeport, IL)
|
Family
ID: |
25519024 |
Appl.
No.: |
05/971,991 |
Filed: |
December 18, 1978 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
|
Reissue of: |
506441 |
Sep 16, 1974 |
03998058 |
Dec 21, 1976 |
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Current U.S.
Class: |
60/652; 290/40B;
290/40C; 60/663 |
Current CPC
Class: |
F01K
7/24 (20130101); F01D 21/00 (20130101) |
Current International
Class: |
F01K
7/24 (20060101); F01D 21/00 (20060101); F01K
7/00 (20060101); F01K 013/02 () |
Field of
Search: |
;60/652,660-667
;290/2,4,4R,52,4B,4C |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Ostrager; Allen M.
Claims
Based on the foregoing what I claim is:
1. In a power system which includes a plurality of prime mover
driven generators, which are interconnected by a plurality of
alternating current transmission circuits, and which include at
least one generator that is driven by a compound type steam turbine
incorporating control valves ahead of the high pressure turbine,
and intercept valves ahead of the turbine or turbines that are
driven by steam that is discharged by the high pressure turbine,
the method of fast valving of the said compound turbine, as a way
to avoid development of system instability, which comprises the
steps of
1. providing within the turbine's control system for a
predetermined response to a fast valving signal input which
response will bring into effect preprogrammed processes of,
a. at least partial closure of the turbine's intercept valves,
.Iadd.effected fast enough to have a favorable effect on generator
rotor first swing stability, .Iaddend.
b. sustained type partial intercept valve reopening.
2. providing in a preprogrammed manner so that,
a. a fast valving signal is generated on the occurrence of
.Iadd.certain types of .Iaddend.system stability endangering events
.[.of a type.]. that cause the said generator to experience a
sudden at least momentary reduction of load,
b. the said fast valving signal is made available as an input to
that portion of the turbine's control system that is adapted to
bring into effect the said predetermined response.
2. The process of claim 1 in which intercept valve reopening is
initiated within 0.1 second of completion of the closing
process.
3. The process of claim 1 which partial intercept valve reopening
carried out in step (1-b) is effected with oil supplied from
accumulators, and is terminated by operation of valves of cam
operated type, with cam position determined by valve stroke.
4. The process of claim 1 in which fast partial intercept valve
reopening, carried out in step (1-b)is effected by the transfer to
the cylinder of each of the valve actuators, of a predetermined
quantity of oil contained within a second cylinder.
5. The process of claim 1, but supplemented by provision of
preprogrammed fast valving signal initiated control valve
repositioning, accomplished rapidly enough, and sufficient in
extent, to prevent an increase of steam pressure ahead of the
turbine's intercept valves that if not prevented, would suffice to
cause discharge of steam through safety valves located ahead of
said intercept valves.
6. The process of claim 1 but supplemented by providing so that
receipt by the turbine's control system of a fast valving signal
input causes discharge of steam to the condenser through .Iadd.one
or more .Iaddend.steam flow control means which are arranged to
receive steam from a point .Iadd.down stream of the high pressure
turbine, but .Iaddend.ahead of the turbine's intercept valves.
7. In a power system which includes a plurality of prime mover
driven generators, which are interconnected by a plurality of
alternating current transmission circuits, and which include at
least one generator that is driven by a nuclear type compound
steamm turbine incorporating control valves ahead of the high
pressure turbine, and intercept valves ahead of the turbine or
turbines that are driven by steam that is discharged by the high
pressure turbine, the method of fast valving of the said compound
turbine, as a way to avoid development of system instability, which
comprises the steps of
1. providing within the turbine's control system for a
predetermined response to a fast valving signal input which
response will bring into effect preprogrammed process of,
a. at least partial closure of the turbine's intercept valves,
.[.,.]. .Iadd.effected fast enough to have a favorable effect on
generator rotor first swing stability, .Iaddend.
b. sustained type partial intercept valve reopening,
c. control valve repositioning of the at least partial closure type
followed by partial reopening so programmed that, to whatever
extent practicable, the time variation of flow of the steam in the
steam and water mixture that enters the separator conforms to the
time variation of steam flow out of the separator, whereby to
minimize change in pressure of steam within the separator,
2. providing in a preprogrammed manner so that,
a. a fast valving signal is generated on the occurrence .Iadd.of
certain types .Iaddend.of system stability endangering events .[.of
a type.]. that cause the said generator to experience a sudden at
.[.lease.]. .Iadd.least .Iaddend.momentary reduction of load,
b. the said fast valving signal is made available as an input to
that portion of the turbine's control system that is adapted to
bring into effect the said predetermined response.
8. The process of claim 7, but supplemented by provision so that
receipt by the turbine control system of a fast valving signal
input initiates a preprogrammed process of reduction of rate of
steam production within the steam generator.
9. In a power system which includes a plurality of prime mover
driven generators, which are interconnected by a plurality of
alternating current transmission circuits, and which include at
least one generator that is driven by a compound type steam turbine
incorporating control valves ahead of the high pressure turbine,
and in which steam discharged from a high pressure turbine passes
into two or more low pressure turbines, each of which is equipped
with a complement of intercept valves, which, when closed, prevent
access of steam to the turbine to which they connect, the method of
fast valving of said compound turbine, as a way to avoid
development of system instability, which comprises the steps of
1. providing within the turbine's control system for a
predetermined response to a fast valving signal input which
response will bring into effect preprogrammed processes of,
a. at least partial closure of the intercept valves of all of the
installation's low pressure turbine, .Iadd.effected fast enough to
have a favorable effect on generator rotor first swing stability,
.Iaddend.
b. thereafter, holding in closed position the intercept valves of
at least one but not all of the said low pressure turbines, while
fully opening the intercept valves of the balance of the
installation's low pressure turbines
2. providing in a preprogrammed manner so that,
a. a fast valving signal is generated on the occurrence .Iadd.of
certain types .Iaddend.of system stability endangering events .[.of
a type.]. that cause the said generator to experience a sudden at
least momentary reduction of load,
b. the said fast valving signal is made available as an input to
that portion of the turbine's control system that is adapted to
bring into effect the said predetermined response.
10. The process of claim 9, but supplemented by provision of
preprogrammed fast valving signal initiated control valve
repositioning, accomplished rapidly enough, and sufficient in
extent, to prevent an increase of steam pressure ahead of the
turbine's intercept valves that, if not prevented, would suffice to
cause discharge of steam through safety valves located ahead of
said intercept valves.
11. The process of claim 9 but supplemented by providing so that
receipt by the turbine's control system of a fast valving signal
input causes discharge of steam to the condenser through steam flow
control means which are arranged to receive steam from a point
.Iadd.down stream of the high pressure turbine, but .Iaddend.ahead
of the turbine's intercept valves.
12. In a power system which includes a plurality of prime mover
driven generators, which are interconnected by a plurality of
alternating current transmission circuits, and which include at
least one generator that is driven by a compound type steam turbine
incorporating control valves ahead of the high pressure turbine,
and in which steam discharged from a high pressure turbine passes
into two or more low pressure turbines, each of which is equipped
with a complement of intercept valves, which, when closed, prevent
access of steam to the turbine to which they connect, the method of
fast valving of the said compound turbine, as a way to avoid
development of system instability, which comprises the steps of
1. providing within the installation's turbine control system for a
predetermined response to a fast valving signal input which
response will bring into effect a preprogrammed process of full
closure of the intercept valves of at least one, but not all, of
the installation's low pressure turbines, while retaining the
intercept valves of the balance of the installation's turbines in
full open position,
2. providing in a preprogrammed manner so that,
a. fast valving signal is generated on the occurrence .Iadd.of
certain types .Iaddend.of system stability endangering events .[.of
a type.]. that cause the said generator to experience a sudden at
least momentary reduction of load,
b. the said fast valving signal is made available as an input to
that portion of the turbine's control system that is adapted to
bring into effect the said predetermined response.
13. The process of claim 12, but supplemented by provision of
preprogrammed fast valving signal initiated control valve
repositioning, accomplished rapidly enough, and sufficient in
extent, to prevent an increase of steam pressure ahead of the
turbine's intercept valves that, if not prevented, would suffice to
cause discharge of steam through safety valves located ahead of
said intercept valves.
14. The process of claim 12, but supplemented by providing so that
receipt by the turbine's control system of a fast valving signal
input causes discharge of steam to the condenser through steam flow
control means which are arranged to receive steam from a point
.Iadd.down stream of the high pressure turbine, but .Iaddend.ahead
of the turbine's intercept valves.
Description
CROSS REFERENCE TO RELATED INVENTIONS
My invention relates in its principal aspect to means for rapidly
controlling power flow within power transmission elements of
interconnected power systems with a view of favorably affecting the
stability of such systems when jeopardized by suddenly occurring
adverse events. This patent application is subject matter related
to my issued U.S. Pat. Nos. 3,051,842, R26,571, 3,515,893, which
has reissued as U.S. Pat. No. R27,842, and U.S. Pat. No. 3,657,552,
and is a continuation in part of my copending applications, Ser.
No. 244,594 filed Apr. 17, 1972, and Ser. No. 388,619 filed Aug.
15, 1973, which have since issued as U.S. Pat. Nos. 3,849,666 and
3,848,138 respectively.
BACKGROUND OF THE INVENTION
1. Field of Invention
The area of utility of the invention comprises prevention of
development of system instability within power systems when
threatened by transmission line faults, and certain other system
stability endangering events.
The area of method comprises responding to faults, and other events
that could endanger system stability, by rapidly initiating
preprogrammed processes of
a. full or partial fast closure of intercept valves of steam
turbine type generator prime movers of power systems, preferably
effected within 1/4 second,
b. subsequent partial reopening of intercept valves, preferably so
effected that the valves begin to reopen somewhat in advance of
occurrence of the peak and the first forward swing of the generator
rotor, and substantially attain planned full extent of partial
reopening within a fraction of a second following that peak.
The preprogrammed processes (a) and (b) may optionally be
supplemented by other control measures, such as, but not limited
to, control valve repositioning and initiation of change in rate of
steam generation by steam supply sources, but employment of such
supplemental measures is not requisite.
2. Prior Art
This invention is similar to, but can be viewed as, in certain
aspects, more basic than that disclosed in the writer's copending
application Ser. No. 388,619, now U.S. Pat. No. 3,848,138.
To ensure adequate description of the prior art, the presentation
contained in U.S. Pat. No. 3,848,138 is to be regarded as
incorporated in this application by reference.
To aid in clarifying how the prior art relates most closely to this
application, it has appeared to be desirable to review what was
involved in the total process of invention under several headings,
as in what follows.
A. INVENTION STATUS OF 1962
In the writer's U.S. Pat. No. 3,051,842 he disclosed the concept of
preprogrammed control valve closure followed by partial reopening,
and in his U.S. Pat. No. R26,571 added the concept of also rapidly
closing and thereafter fully opening intercept valves, but he did
not discuss steam generator controls, or the behavior of safety
valves.
B. STEAM GENERATOR CONSIDERATIONS
Actually, where what was being dealt with was fossil fuel fired
steam generators, of U.S. design, supplying superheated steam to
both high and intermediate pressure steam turbines, there was
inherent a need to reduce fires, as in a matter of a minute,
following a first sustained reduction of high pressure turbine
steam acceptance, effected as a result of fast valving, in order to
protect the reheater from overheating.
Also during this 1 minute period the high pressure safety valves
would be discharging steam to atmosphere, except to the extent that
occasion for them to do so would be avoided, or minimized, as a
result of the operation of often, but not always, provided, power
operated, or so called "powermatic," valves that are arranged to
open in response to a rise in steam pressure, and that provide a
substitute means of diversion of steam to atmosphere.
Also where, as the writer discovered, typically, provision was not
being made for opening intercept valves faster than in a matter of
10 seconds, it could apply that if control valves were not closed
sufficiently, reheat pressure safety valves could also lift and
discharge steam.
Further, the point came up that when steam discharges through
safety valves, particles of metal that would be carried over from
the boiler, or the superheater, or the reheater, could cause damage
to the seal surfaces, and prevent perfect reseal when the valves
reclosed, with the effect that it would be necessary to schedule a
unit shutdown to allow repairs, which sort of thing typically would
involve considerable expense, in view of the unit being taken out
of service, and the requirement of temporarily generating
substitute power with older and less efficient machines.
Now, actually, as see reference 69 of the table of references, it
appears to be possible to so thoroughly clean boilers,
superheaters, and reheaters, that safety valves are seldom if ever
damaged, when they discharge steam, which approach is, or has been,
successfully used by Ontario-Hydro, as a way to prevent safety
valve damage on trip-off to auxiliary load, which they have
commonly employed when tripping a unit off the line.
Also, it can be argued, that, at least when fast turbine valving is
to be seldom invoked, it would be possible to merely tolerate the
damage that lifting of safety valves induces, which, it may be
noted, is the policy that applies at the Four Corners station of
Arizona Public Service, where a 750 mw unit is typically tripped
off under load four times a year, in response to line faults, as a
way to avoid loss of intersystem ties on the occurrence of
permanent type faults (cf ref. 25).
However, considering the attitude of those power system engineers
who are directly concerned with the operation of power plants, it
became incumbent on the writer to seek solutions to the problem of
safety valve lifting, and, with this in mind, when the original of
U.S. Pat. No. R27,842 was written, he included in it, as see par. 3
of column 24, the statement
"I propose to avoid operation of the high pressure safety valves by
providing fast acting and fully commercially available dump valves,
which are programmed by the fast turbine control system to dump
high pressure steam, either to atmosphere, or preferably, to the
turbine condenser, with concomitant supply of spray water for
cooling purposes." the idea being to employ enough dump valves to
eliminate lifting of safety valves.
When it came to valves for dumping high pressure steam, powermatic,
pilot operated type valves were already commercially available,
while also it is feasible to provide shut off valves ahead of them,
which, when done, allows repair without need to schedule a unit
shutdown.
However, there was a question as to what to employ when it came to
providing dump valves for use at reheat pressure.
In 1964, in discussion of this problem with personnel of the Crosby
Valve Co. of Wrentham, Mass., the point came out that safety valves
can be converted to power operated valves, and hence to "dump
valves," by equipping them with air operated lifting devices which,
it was claimed, would cause the valves to lift in a fraction of a
second, while the point also applied, that if used to supplement
safety valves, these valves could also be mounted downstream of
shut-off valves.
Thus when the original of U.S. Pat. No. R27,842 was written the
writer knew how to proceed to make available normally non-leaking
valves for dumping both high and reheat pressure steam to
atmosphere, with provision to allow maintenance when required,
absent need to schedule a unit shutdown.
C. CONCEPT OF SUSTAINED PARTIAL INTERCEPT VALVE REOPENING
As it turned out the availability of non-leaking bypass valves,
adapted for use at reheat pressure, led the writer to the idea that
it would be possible, and that it could also be desirable, to have
recourse to restricting the extent of reopening of intercept
valves, whereby to effect a sustained reduction of turbine driving
power by this means, and it was with this in mind that he included
in the application for the original of U.S. Pat. No. R27,842 the
statement (cf par. 7 column 24)
"Also, it will be clear that where a sudden, sustained drop in
driving power of a reheat type turbine is wanted, it will be only
feasible to achieve desired results by using the intercepting valve
as a steam flow modulation device to supplement control valve
modulation of steam flow to the high pressure turbine which,
however, it is judged can be accomplished by those skilled in the
art merely with application of generally known practices (21,
22)."
However since the statement does not describe what, in detail,
would be done, it is not thought to anticipate either what is
disclosed in copending application 388,619, now U.S. Pat. No.
3,849,666, or the concept of effecting a type of preprogrammed
intercept valve reopening that would terminate valve motion at a
partly open position, that is covered in the present
application.
The new concept of the present application, it may be noted, offers
certain advantages in the way of simplicity, and can be used
where
a. as in Continental European type once-through fossil fuel and
also HTGR, high temperature gas cooled reactor type nuclear
installations, the high pressure turbine is provided with a by-pass
to the cold reheat line,
b. in those nuclear installations in which extent of reheat is
slight, and there is therefore no problem of protection of the
reheater from overheating,
c. when control valves either are held open, or are first rapidly
fully or partly closed, and then fully opened,
as also when
d. sustained .Iadd.partial .Iaddend.control valve closure is
employed and is supplemented by initiation of a reduction in rate
of steam generation within the steam supply source,
but the notable feature is that sustained driving power reduction
can be effected without need to program a change in steam
generation when any of control procedures (a), (b) or (c) above are
made use of, a feature of importance since, with use of these
techniques, when a faulted line has been opened on a temporarily
sustained basis, either as a matter of general policy, or because
of development of a refault on automatic circuit breaker reclosure,
if and when the line is, perhaps, quickly restored to service, it
becomes possible to reestablish full generator output in a matter
of seconds, since there had been no need for recourse to the slow
and also slowly reversed process of change in rate of steam
generation.
D. HISTORY OF THE CONCEPT OF EMPLOYING LOW PRESSURE STEAM BY-PASS
VALVES AS A WAY TO SOLVE THE PROBLEM OF FAST VALVING TURBINES THAT
RECEIVE STEAM FROM BOILING WATER TYPE REACTORS
Beginning in April 1966 the writer endeavored to interest
Commonwealth Edison in equipping two GE nuclear type turbines with
provision for fast turbine valving.
This led, in due course, to stability studies that demonstrated
ability to deal with the problem of delay in fault clearance.
However, when it came to fast valving these turbines, which were to
be installed in a power station named Quad Cities, studies carried
out by GE Schenectady, which were based on purely momentary
intercept valve closure, established that a problem would develop,
in that, due to slow reopening of intercept valves, it could be
predicted that pressure ahead of the low pressure turbine would
rise when fast valving was invoked, and this, in turn, would cause
a rise in the pressure ahead of the high pressure turbine, that
would cause a hazard of scramming the reactor, which was of the
BWR, or boiling water type, that GE was producing at San Jose.
On looking into what was involved, the writer determined that it
had become GE San Jose practice to use spring loaded valves, of a
modified type, which Crosby Valve had been producing, as a means of
discharging 1,000 psi steam to the containment vessels of its BWR
reactors, the modification consisting in applying a bellows which
would seal the path of discharge steam and, with the valve in
closed position, prevent leakage of air into the condenser.
It then occurred to the writer that these valves could be converted
to a fast acting power operated type by equipping them with air
operated lift cylinders, and that they could be used as a way to
solve the Quad Cities units fast valving problem by providing so
that they would respond to a fast valving signal by popping open
and discharging to the condenser, either,
a. high pressure steam, or
b. low pressure steam.
To progress this idea further Crosby Valve agreed to carry out
tests which would demonstrate speed of operation, and this was
done, first on a small valve in July of 1967, and later, in
November, on a larger valve, of the size used in nuclear
installations.
GE had previously considered using air lifted valves in a BWR
installation but had given up the idea on the assumption that they
would not be fast enough.
The November test, which was witnessed by GE personnel, showed that
the valves could be opened in less than 1/10th second, while also
Crosby Valve planned to step up speed to 1/20th second, which was
judged by GE to be sufficiently fast.
The November test led to GE San Jose thereafter incorporating the
air lift feature as an element of its high pressure relief
valves.
Also San Jose accepted that use of air lift valves ahead of either
the high or low pressure turbine could be used as a way to prevent
reactor scram as a result of use of fast valving, but, as it turned
out, Commonwealth Edison decided against use of fast valving on the
theory that it might cause problems that would prove to be a source
of difficulty and so nothing was done.
However the idea of utilizing a power operated fast acting low
pressure relief valve as a way to limit rise of pressure ahead of
the low pressure turbine, and hence, also ahead of the high
pressure turbine and within reactors of BWR type, when fast valving
was employed, remained as a presumably entirely workable
concept.
Also as early as November 1967 the writer brought to the attention
of the Crosby Valve Co. the point that a market could develop for
valves that would by-pass around both low pressure turbines of
nuclear units and intermediate pressure turbines of fossil fuel
steam source type, as a way to allow fast valving of the sustained
reduction of driving power version.
In continuation, in 1969 the writer took up with Crosby Valve the
matter of the cost of equipping the spring loaded low pressure
relief valves of TVA's Browns Ferry BWR reactor type nuclear steam
electric units with air lifters.
This was at a point when TVA was giving consideration to use of
fast valving of the sustained reduction of driving power type at
Browns Ferry, something that they were deflected from as a result
of representations by GE Schenectady as to the possibility of
problems with the drain system of the moisture separators.
Rather than provide to fast valve at Browns Ferry, TVA decided to
ask for this feature as an option in the case of two 1300 mw
nuclear units that were to be installed in a station at Watts
Bar.
Since Westinghouse was a bidder and could provide sustained
reduction of driving power with use of its PWR pressurized water
reactors, which were equipped with 45 percent high pressure by-pass
systems, and since Westinghouse was not prepared to hold its
intercept valves in a fixed modulating position, the concept of
providing for use of sustained partial intercept valve reopening
was not raised, and this also applied when it later came to a
similar nuclear station that was to be located at Bellefonte, and
that would utilize a Babcock & Wilcox PWR type nuclear
reactor.
In 1973 the question again came as to the feasibility of fast
valving a TVA BWR installation, this time in relation to a plant to
be located at Hartsville which would incorporate four 1220 mw
turbines that would be supplied with steam from GE BWR type
reactors.
The Hartsville turbine award went to Brown Boveri, which concern
quoted on provision of fast turbine valving of the sustained
reduction of driving power type as an extra cost option.
Brown Boveri has, since the award, been in touch with GE San Jose,
and reportedly there has been consideration of employing air
lifting of spring loaded low pressure relief valves as a way to
avoid a reactor scram, but, to my knowledge, there has been no
published account of employment of sustained partial reopening of
intercept valves as a means of effecting sustained reduction of
driving power type fast valving in BWR steam electric
installations.
E. HISTORY OF THE CONCEPT OF USE OF SUSTAINED PARTIAL LIFTING OF
INTERCEPT VALVES AS A MEANS TO PROVIDE FOR FAST VALVING OF THE
SUSTAINED REDUCTION OF DRIVING POWER VERSION IN THE CASE OF REHEAT
TYPE FOSSIL FUEL STEAM ELECTRIC INSTALLATIONS
The concept of utilizing electrically controlled air assisted
spring loaded valves as by-pass valves that would discharge steam
from a point just ahead of an intermediate pressure turbine of a
fossil fuel steam electric installation to make possible sustained
partial lifting of intercept valves as a way to accomplish
sustained driving power reduction type fast valving, yet avoiding
lifting of reheat pressure safety valves, was gone into with Crosby
Valve as early as the latter part of April 1964 though this was in
the context of using these valves to divert steam to atmosphere for
the period of time required for fast as feasible reduction of
boiler fires, since, at that time, these valves were not understood
to be capable of being adapted to allow the discharge of steam to
the condenser.
It was recognized that other types of fast acting valves, that
could be used to discharge to the condenser, were available, but
engineers of Ebasco Services, with which contact was established in
1966, took the position that leakage would represent an
insurmountable obstacle to their use.
However, the availability, as of 1967, of sealed type spring loaded
valves such as were developed for use in connection with BWR
nuclear installations, coupled with the approach of installing
isolation valves around these valves as a way to allow repair
without scheduling a unit shutdown, provided a way out of this
difficulty.
Standing in favor of sustained partial intercept valve lifting is
the fact that it can be used as a way to either avoid or minimize
need to readjust rate of steam generation, while standing against
it is the expense of providing the valves and their shutoffs.
At the 1969 American Power Conference, a Siemens paper (35)
described the German practice of regularly equipping oncethrough
boiler steam electric installations with by-pass systems that
diverted steam both around the high pressure turbine to the cold
reheat line and from the hot reheat line to the condenser, as both
control and intercept valves were simultaneously partly closed in
response to change in speed in the event of sudden partial loss of
load which at once made clear that, when it came to Germany,
sustained driving power reduction type fast valving for stability
improvement purposes, would be very easy to provide.
However, as also brought out in the statement of the prior art
contained in the writer's application Ser. No. 388,619, now U.S.
Pat. No. 3,848,138, the writer took up with Siemens and later with
M.A.N., the idea of providing response to line faults as a means of
improving system stability, while the idea was viewed as certainly
new, it was not accepted as providing a solution to an economic
need.
Also, although an article on electrohydraulic turbine control
systems that appeared in a recent issue of Elektra (66)* discusses
fast valving, (as see sections 3.4 and 5.8), and stresses its
potential importance, though techniques of fast valve closure and
fast full reopening are cited, no mention is made of partial
reopening of either control or intercept valves, and while there
is, in the U.S. literature reference to sustained partial opening
of control valves after fast closure effected for purposes of
improving power system stability (21, 22, 23, 25, 67), the writer
fails to recall any instance of published reference to sustained
partial opening of intercept valves following an initial process of
closure in the context of a measure intended for improvement of
stability.
F. PROVISION TO PROVIDE AGAINST DEVELOPMENT OF INSTABILITY OF DRAIN
SYSTEMS OF MOISTURE SEPARATORS, AS A CONSEQUENCE OF APPLICATION OF
FAST TURBINE VALVING TO BWR AND PWR TYPE NUCLEAR STEAM ELECTRIC
INSTALLATIONS
When it comes to BWR and PWR type nuclear installations GE
Schenectady has stressed the fact that fast valving might cause
objectionable instability of moisture separator reheater drain
systems.
Here the point that applies is that decrease in MSR pressure tends
to cause the flashing into steam of water contained in the drain
system, and can result in a surge of drain water back into the
MSR.
This is a problem that also develops when the steam acceptance of
the high pressure turbine is reduced, whether as a result of
closure of control valves, or reduction of rate of steam
generation, but the problem is not consequential if rate of steam
acceptance, and hence also MSR pressure reduction, does not exceed
a valve which depends, in part, on the way the MSR drain system is
designed.
When control valves are held open, and intercept valves are fully
closed, and thereafter fully opened, and especially if they are
reopened slowly, MSR pressure will at first increase, but, in due
course, will decrease to the value that applied prior to initiation
of fast valving, and it has been the fact that the process of
decrease could cause MSR drain system instability that GE has
warned against.
Pressure increase is greatest when intercept valves open slowly,
and since this fact is readily understood by those skilled in the
art, it should be, and in some quarters has been, obvious that
speeding up the process of intercept valve reopening would minimize
it, and it would presumably be obvious, in turn, that such
reduction of pressure rise would operate to minimize rate of
subsequent MSR pressure drop.
However, I have conceived of additional techniques for reducing
rate of MSR pressure drop consequent on fast valving, which
measures are disclosed in this application.
Also, where there has been and remains a good deal of power
industry concern as to the MSR drain system problem, and a chance
that it could, if indeed it does not already, stand in the way of
employment of fast valving of BWR and PWR nuclear installations,
the fact that the techniques hereinafter described for avoiding or
largely minimizing rate of MSR pressure drop, as it would appear,
have not heretofore been advocated, would .[.seam to be well
indicated that they are not obvious..]. .Iadd.seem to indicate
nonobviousness. .Iaddend.
G. PROVISION TO SELECTIVELY REPOSITION INTERCEPT VALVES OF LOW
PRESSURE TURBINES OF NUCLEAR STEAM ELECTRIC INSTALLATIONS, AS A
MEANS OF EFFECTING SUSTAINED TYPE FAST VALVING FOR PURPOSES OF
STABILITY IMPROVEMENT
This application introduces the concept of selectively effecting
preprogrammed processes of closing and reopening of intercept
valves located ahead of low pressure turbines of nuclear type where
more than one low pressure turbine receives power from a single
high pressure turbine, with the objective of improving power system
stability when jeopardized by suddenly occurring events.
Not only has there been no evidence of any prior art in this area,
but the concepts involved, when explained to turbine control
people, have been viewed as novel.
SUMMARY OF THE INVENTION
The invention has relation to improved methods for rapidly varying
the driving power of turbines by repositioning intercept valves,
and optionally also simultaneously repositioning control valves and
controlling the operation of steam supply systems, whereby to avoid
development of power system instability when jeopardized by
transmission line faults and other stability endangering events,
while at the same time avoiding damage to equipment.
Generator drive systems of power system steam-electric
installations comprise a high pressure turbine, plus one or more
low pressure turbines, plus, in the case of installations in which
steam is generated with use of fossil fuel, or with an HTGR or high
temperature gas cooled type nuclear reactor, one or more
intermediate pressure turbines which are operated with steam that
is highly superheated in reheaters.
Control valves are employed to control supply of steam to high
pressure turbines and intercept valves are provided immediately
ahead of intermediate pressure turbines and low pressure turbines
of nuclear installations which do not intensively reheat steam
discharged from the high pressure turbine.
In the U.S., at least, it is common practice for the first stage of
a high pressure turbine to be of the impulse type and for first
stage nozzles to be grouped into segments with the steam supply to
each segment individually controlled by means of individually
operable control valves.
It also was, at one time, a common practice and it remains feasible
to employ by-pass type control valves that admit high pressure
steam to intermediate stages of high pressure turbines.
Providing to automatically fully or nearly fully close intercept
valves in response to an indication of a line fault, and thereafter
fully reopen, offers a way to decrease the tendency for power
system generators to lose synchronism as a result of line faults
and other system stability endangering events, but momentary
closure of this type tends to increase pressure within reheaters
and moisture separators, with two effects,
1. the post-fault or more generally the post stability endangering
event driving power of the turbine or turbines down stream of the
intercept valve or valves will exceed the pre-fault, or pre-event
driving power, a circumstance which tends to adversely affect
system stability, this being especially the case when the fault or
other stability endangering event results in the sustained opening
of one or more transmission system circuit breakers, and thereby
operates to impede transmission of power in the post-fault or
post-event regime, whereas actually it would normally be
advantageous for the total post-fault or post-event driving power
of the turbine to be held less than, and, as a rule, preferably
somewhere in the range of 60 to 90 percent of pre-fault or
pre-event value,
2. reheat and MSR (moisture separator and moisture separator
reheater) pressure safety valves may discharge steam and in some
cases may thereafter leak and require maintainance.
One proposed approach to the solution of problem (2) above is to
speed up the process of intercept valve reopening, while another is
to raise the setting of the reheater and MSR pressure safety
valves.
However these approaches do not solve problem (1).
An obvious way to avoid both problem (1) and (2) is to reposition
control valves so as to reduce high pressure turbine steam
acceptance on a sustained basis.
However, there has been reluctance on the part of engineers to
employ this procedure because of the conviction that it would be
difficult and expensive to provide so that it could be effected
without lifting of high pressure safety valves, which, when
occurring, is likely to cause damage to the valves that can require
scheduling a unit shutdown to allow effecting repairs.
Also, in the case of fossil fuel fired installations, there has
been concern as to the feasibility of readjusting fuel, water and
combustion air supply rapidly and accurately enough to prevent
damage to reheaters due to overheating, and as to whether what
would be done would cause objection from the standpoint of
excessive thermal fatigue damage to turbines.
Further, in the case of boiling water reactor, or BWR type nuclear
installations, there are stringent limitations in respect to the
extent to, and speed with which, control valves can be closed.
In the present invention the problems presented are dealt with by
employing a method of fast valving which brings into effect
preprogrammed process of,
1. intercept valve closure which are fast enough and sufficient in
extent to have a favorable effect on generator rotor first swing
stability, and preferably take the form of full closure effected in
1/4 second or less,
2. subsequent reopening of some or all intercept valves to a
partially open position with reopening preferably initiated
somewhat in advance of the first forward swing of the generator
rotor, and carried to completion within a fraction of a second
following the peak of that swing,
coupled with
3. preprogrammed servo valve implemented retention of partially
opened intercept valves in, or substantially in, the preprogrammed
position that they attained in their rapidly executed reopening
process,
with which techniques the intercept valves assume and retain a
partially opened position at the end of a preprogrammed
repositioning cycle, until such time as an election is made to
further reopen them.
In the case of turbines in which steam from a high pressure turbine
passes directly to two or more low pressure turbines the above
procedures may optionally be modified by either closing and holding
closed the intercept valves of only one or more but not all low
pressure turbines, or closing the intercept valves of all turbines
and thereafter rapidly opening the intercept valves of one or more
but not all turbines.
In one approach discharge of steam through reheat and low pressure
safety valves can be tolerated, which, if planned on, can be
favorably implemented, on a control basis, by providing so that
electrically controlled air operated lifters will be applied to a
predetermined number of spring loaded type valves, and that those
valves will be lifted in response to a fast valving initiation
signal.
In an alternate approach, which is consonant with practices that
commonly apply in the case of continental European steam electric
installations of fossil fuel type (35, 65, 66, 70, 71), opening of
reheat or low pressure safety valves is prevented by provision of
servo controlled by-pass systems that discharge desuperheated steam
either from the hot reheat line, or, in the case of BWR type
nuclear installations, from a point just ahead of the low pressure
turbines to the condenser, in response to increase in steam
pressure.
In still another approach prevention of discharge of steam through
reheat or low pressure safety valves of PWR type nuclear or fossil
fuel installations is prevented by employment of preprogrammed
control valve repositioning.
Where discharge of steam through reheat or low pressure safety
valves is tolerated, as also where power operated reheat or low
pressure steam by-pass systems are employed, provision to close
control valves is optional, while if control valve repositioning is
employed election can be made to employ any of the following
preprogrammed procedures.
1. full or partial closure followed by full reopening,
2. full or partial closure followed by partial reopening,
3. partial closure.
From the standpoint of preservation of system stability, control
valve full closure in 1/4 second or less is advantageous,
preferably followed by comparably fast full or partial reopening,
with initiation of reopening adjusted to take place so that full
extent of preprogrammed reopening is achieved within a fraction of
a second following completion of the first forward swing of the
generator rotor.
Where boiling water reactors represent the steam supply source, it
becomes necessary to limit the speed of control valve closure and
to avoid closure that, even momentarily, causes a reduction of
steam acceptance of the high pressure turbine that exceeds the
capacity of the turbine's high pressure by-pass system.
In steam electric installations in which, following continental
European practice, desuperheating type steam by-pass systems are
provided as a way to automatically by-pass superheated steam around
the high pressure turbine to the cold side of a reheater located
ahead of an intermediate pressure turbine, control valves can be
rapidly repositioned in any desired degree, on a sustained basis up
to a point dependent on the capacity of the by-pass system, but
would preferably be fully closed and thereafter partly reopened to
a point at which the steam supplied to the cold reheat line
coincides with the steam acceptance of the intermediate pressure
turbine, at the time of completion of preprogrammed partial
intercept valve reopening.
In the case where the steam supply source comprised a PWR, or
pressurized water type reactor, there would normally be no
restriction on fast full closure of control valves, provided that
they were promptly reopened to a point at which reduction of high
pressure turbine steam acceptance did not exceed the capacity of
the turbine's high pressure by-pass system.
In the case of both PWR and BWR reactor type steam supply sources,
it can be advantageous to minimize both moisture separator reheater
depressurization and extent of pressure rise, which implies, that,
in the case of PWR installations, it is important to closely relate
the extent of preprogrammed reduction of steam acceptance of the
high pressure turbine to that of the low pressure unit.
Implementation of intercept and control valve repositioning can
take some or all of several types of preprogrammed procedures
listed below.
a. fully closing all intercept valves in a fraction of a second by
rapidly opening valve actuator oil dump valves,
b. fully or partly closing all intercept valves under servo
control,
c. after initial full or partial closure of all intercept valves,
repositioning under servo control,
d. supplementing item (c) by fast partial intercept valve reopening
initiated somewhat in advance of the generator rotor first forward
swing, preferably effected within 1/2 second, with control of
extent of reopening determined with use of metering cylinders or
with servo or cam operated valves,
e. fully closing all or some control valves in a fraction of a
second by rapidly opening valve actuator oil dump valves, or
f. fully or partly closing all control valves under servo
control,
g. after initial full or partial closure of control valves, fully
or partly reopening under servo control
h. supplementing item (g) by fast full or partial control valve
reopening initiated somewhat in advance of the instant of generator
rotor first forward swing, and preferably effected within 1/2
second.
Supplementary preprogrammed initiation of reduction of rate of
steam generation and initiation of steam by-passing operations and
of discharge of steam to atmosphere can also, optionally, be
employed, and provision of a supplementary preprogrammed process of
full opening of intercept valves can additionally be elected.
A main object of the invention is to allow, via provision in
generating station design, so that power transmission lines can be
subjected to higher transmitted power loadings than could otherwise
be employed without a consequent increase in hazard of development
of system instability on the occurrence of line faults and certain
other system stability endangering events.
Another object is to increase the amount of power that can be
safely transmitted over a right of way of given width.
A further object of the invention is to allow increasing the amount
of power that can be transferred over a line operated at a given
voltage.
Another object of the invention is to provide so as to minimize
hazard of development of system instability in the event of
infrequently occurring severe contingencies such as delay in fault
clearance.
Another object of the invention is to achieve the above objectives
in a manner that minimizes generating station first and operating
costs including costs related to providing for steam bypassing and
for discharging steam to atmosphere via power operated valves, and
that avoids need to take generating units out of service to allow
repairs.
Another object of the invention is to provide improvements in
generating station design which increase effectiveness and
eliminate or minimize penalties in employment of fast turbine
valving, whether or not supplemented by employment of dynamic
braking, as a way to prevent cascading type system instability.
Another object of the invention is to avoid development of system
instability subsequent to the occurrence of first generator swings
following a line fault or some other system stability endangering
event.
Another object of the invention is to avoid situations where, even
though a generator remains in synchronism following a fault on a
line tieing it to a system, the disturbance resulting from the
fault has the effect of causing loss of sychronism of some other
generator or generators.
Another object of the invention is to effect fast turbine valving
for system stability improvement in ways which do not necessitate
readjustment of rate of steam generation within steam
generators.
Another object of the invention is to effect fast valving of steam
electric installations which receive their steam from either PWR or
BWR nuclear steam supply sources, in such manner as to eliminate
significant reduction of moisture separator reheater pressure,
whereby to avoid instability of MSR drain systems.
Still another object of the invention is to prevent the scramming
of the reactor when provision for fast valving for stability
improvement purposes is made in BWR type nuclear steam electric
installations.
It is an important element of the invention that it can be usefully
employed as an aspect of a process of combined fast valving and
momentary application of braking load.
BRIEF DESCRIPTION OF DRAWINGS
The subject matter which is regarded as the invention is capable of
being implemented in a variety of ways. In practice what is
necessary to facilitate its employment is to devise ways to apply
it in power system steam electric installations of already
developed types, with a minimum need to introduce changes in design
that would be costly and time consuming to put into effect.
Therefore the drawings have been prepared in this context.
In the drawings
FIG. 1 is a simplified schematic view of a typical fossil fuel type
steam turbine driven generating unit of U.S. design to which is
coupled a drum boiler type of steam generator,
FIG. 2 is a simplified schematic view of the No. 2 unit of TVA's
Cumberland generating station in which a Brown Boveri cross
compound turbine receives its steam from a Babcock & Wilcox
once through steam generator,
FIG. 3 is a simplified schematic view of a large nuclear turbine
which is supplied with steam from a nuclear steam supply source
which could be of either the boiling water (BWR) or pressurized
water (PWR) reactor type,
FIG. 4 is a simplified partial representation in schematic form of
an arrangement adapted to rapidly reopen a closed turbine steam
admission valve but do so part way only,
FIG. 5 represents an exterior view of an intercept valve that has
been provided with means for effecting fast partial reopening,
FIG. 6 comprises FIG. 1, modified to include a desuperheating type
by-pass system that is arranged to discharge steam from the hot
reheat line to the condenser.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
In FIG. 1 water that has drained down to the bottom of condenser 1
is pumped by pump 2 through low pressure feed water heater system 3
to deaerator 4 from which point it flows to boiler feed pump 5
which is driven by boiler feed pump turbine 6 which receives steam
from one or more sources not shown through valve system 7.
From the boiler feed pump water passes into high pressure feed
water heater system 8, next to economizer 9 and next into drum 10
from which it passes to the bottom of and up through furnace 11 and
returns to the drum as wet steam.
The steam so produced next passes through superheater 12, stop
valves 16 shown for convenience as a single valve, but normally
consisting of four valves one being series connected to each of the
four control valves 17 of partial admission type high pressure
turbine 18, wherein the nozzles ahead of the control stage of the
turbine are divided into four segments which are supplied with
steam individually through the four control valves.
After passing through the control valves and the turbine the steam
enters reheater 19 and from there flows through a pair of stop
valves 21 and series connected control valves 22, and then into
intermediate pressure turbine 23 and from there to low pressure
turbine 24 and from there flows into the condenser where it is
reconverted to water. The three turbines are coupled together in
line and drive generator 26 which supplies three phase power to
three transformers 31 through generator output leads 29. In the
transformer 31 the voltage is stepped up from typically around
22,000 volts to a voltage which is today typically in the range of
345 to 500 kv, and can range up to 765 kv.
The transformer connects to switching station 32 through a pair of
circuit breakers 37 and 38, shown conventionally as square boxes,
which are to be understood to represent two of a larger number of
circuit brakers not shown in the drawing by which the generator
makes connection to transmission lines L.sub.1, L.sub.2 and L.sub.3
and, in the bulk of cases, also to at least one other generator
located within the same station that houses the generator
shown.
Transmission system responsive control system 33 is to be
understood to incorporate a protective relaying system which acts
to cause the opening of circuit breakers at which lines terminate,
on the occurrence of line faults, and in the case of certain other
events, and is to be understood to incorporate also fast valving
signal generating and logic means which may and usually would be
made responsive to one or more parameters of system prefault or,
more generally pre-system disturbing event system conditions, such
as lines not in service and the magnitude of generated and
transmitted power, plus the fact of occurrence of a fault or other
event of a type that could endanger system stability, which in the
case of a fault can depend on fault type and location, while also
the control system may be arranged to respond to the occurrence of
a stuck breaker or some other post instant of fault initiation
event, or to the extent and distribution of line fault induced
reduction in power flow over one or more lines, or in respect to
the extent and rate of reduction of the power output of generators,
(57, 58).
Procedures of these types and others directed to determining when
to initiate and to modify fast valving cycles have already been
described in several patents (3, 21, 22, 23, 46, 54) one of which
has already expired, while certain additional procedures are
described in the writer's pending patent application ser. no.
244,594.
In addition control system 33 usually receives information by
carrier current or some other channel of communication which has
relation to power flow over intra and inter system tie lines and as
to the power output of other generators located in and remote from
the station, which information is used to develop a signal that is
created for the purpose of suitably modifying the load reference of
the turbine's control system so as to cause the turbine to become a
participant in programs of tie line power flow control and system
economic dispatch (53).
Also as shown by the dotted line connecting polyphase watt
transducer 36 which is connected to current transformers 34 and
potential transformers 35 and which generates a signal proportional
to generator power output, control system 33 receives such a signal
as one of its inputs.
Turbine and steam generator control system 39 receives as inputs
the outputs of generator rotor speed transducer 27, which usually
appears in the form of a frequency signal which is generated by a
magnetic pick-up which is influenced by a toothed gear on the
generator shaft, and in addition receives as inputs an output from
watt transducer 36 and outputs from transmission system responsive
control system 33 which take the form of turbine governor load
reference modification signals generated as aspects of tie line and
economic dispatch control systems and also one or more types of
signals which initiate fast valving, or that may relate to what
will be preprogrammed to be done when fast valving is
initiated.
Thus the dotted line that in FIG. 1 runs from transmission system
responsive control system 33 to turbine and steam generator control
system 39 is to be understood to include as a minimum two channels
of information transfer namely one that is used to modify the
turbine's load reference system as an aspect of tie line and
economic dispatch control systems and at least one fast valving
signal transfer channel.
However it is also to be understood that optionally, in addition,
the number of information channels can be expanded to allow
selective initiation of more than one type of preprogrammed fast
valving cycles, and to permit modification of the parameters of
such programs in response to such factors as system conditions
existing prior to a line fault or other system stability
endangering event, and the occurrence and nature of post fault
events.
Coming now to the functions of turbine and steam generator control
system 39 these are in the first instance to continuously control
the position of the turbine's control valves 17 and also valve
system 7 of the boiler feed pump turbine 6 and boiler fuel and air
supply control system 54, and in addition the position of control
and intercept valves in response to fast valving signals where the
object is system stability improvement and also as an aspect of
turbine overspeed control systems which systems may also provide
for control of stop valves 16 and 21 though in the first instance
these stop valves are controlled by emergency governors that
represent a built-in feature of the turbine.
When it comes to providing to implement fast valving one useful
thing to do that has not been provided for in U.S. steam electric
installations to date with exceptions in the case of Four Corners,
and TVA's stations Cumberland and new stations comprises
1. effecting a process of sustained partial control valve closure
with a view to avoiding development of instability on generator
rotor second and following swings and in the steady state following
loss of one or more lines, and as a way to avoid need to trip-off a
generator such as could otherwise apply.
Also another new but desirable thing to do is to
2. so provide that the curve of turbine driving power versus time
begins to rise at about the time that the generator rotor has
attained the peak of its first forward swing so as to reduce the
extent of generator rotor first backward and second and following
forward swings (56).
Also a further thing that is desirable is to
3. avoid lifting high pressure safety valves 40 or 41 in order to
prevent damage that could require scheduling a turbine shutdown for
the purpose of effecting reapairs.
Objectives (1) and (3) tend to be in conflict in that reduction of
high pressure turbine steam .[.accepts.]. .Iadd.acceptance
.Iaddend.such as occurs when control valves close operates to cause
increase in pressure ahead of the turbine. .[.However provision.].
.Iadd.Provision .Iaddend.of one or more power operated relief
valves 42 which often are arranged to make connection to the high
pressure steam line ahead of the turbine stop valve through
shut-off valves 44, and which are arranged to open when a pressure
operated switch in control unit 43 senses the fact that steam
pressure in the steam line exceeds a preset value.Iadd., can
provide a solution. .Iaddend.
However, providing a sufficient number of these valves to prevent
lifting of valves 41 adds to the expense of the station, and
especially when, due to sluggishness of servo controlled valve
repositioning, it would be useful from a fast valving standpoint to
at first fully close thereafter reposition control valves to a
partially open position.
However there is a feasible way around this problem which can be
viewed as obviously offering advantages once it is grasped but that
has not given evidence of being at once obvious to those skilled in
the art, or who would profess to be skilled in the art of fast
valving for system stability improvement, namely to provide to
close two out of the total of four control valves that are commonly
employed on partial admission type turbines, which brings with it
the opportunity to rapidly reduce turbine steam acceptance to
around 65 percent when starting from an initial condition of full
load.
Alternatively it can be elected to provide to close only one valve,
which however reduces driving power only about 8 percent or
thereabouts.
Broadly the concept is to rapidly close some but not all control
valves, so as to take advantage of what is feasible when partial
admission is used.
Apparently there would be objection on the part of turbine
producers to the rapid closure of more than half but less than all
of the turbines control valves so that in practice not more than
half would be so closed.
Also it is a feature of the present invention that, at the same
time that a pair of control valves, or only one valve, would be
rapidly fully closed by valve actuator oil dumping, the load
reference of the speed governing mechanism would be rapidly reset
and the dump valves rapidly reclosed so as to cause all valves to
begin to move toward new preprogrammed positions under servo
implemented feed back type control.
How in detail the foregoing can be provided for can be well
understood by referring to U.S. Pat. No. 3,602,617 (54) which
describes means for rapidly closing both control and intercept
valves and for equally rapidly modifying turbine load
reference.
Thus, referring to FIG. 1 of the patent, it will be seen that if
provision is made to replace the unbalance relay logic therein
identified as item 9 by preprogrammed fast valving logic provided
within turbine and steam generator control system 39 and initiated
in response to a transmission system responsive control system 33
fast valving signal output, what is wanted will be fully
accomplished if
a. the connections from the logic system to trigger 17 are opened
in the case of two (or three) control valves, and
b. the modifier is preset to bring about the desired sustained
partial reduction in turbine load, rather than zero export load,
such as the patent stipulates.
Coincidentally with causing control valve repositioning the fast
valving signal would be arranged to suitably modify boiler fuel and
water supply by temporarily disabling usual feed back controls and
imposing a fast runback type of control action which will have the
effect of readjusting the rate of fuel and feed water supply to new
values that will be approximately in balance with the preprogrammed
new sustained value of high pressure turbine steam acceptance in
the post-fault or more generally in the post system stability
endangering event regime.
It is not necessary to disclose in this application the details of
how this would be done because means of providing fast runback of
fuel and feed water supply, and hence steam generation, have for
long been commercially available from leading boiler and/or boiler
control producers and at most would require some degree of speeding
up. (61,62).
Since if valves 42 open quickly such opening will slow down
pressure build up in the superheater it also applies that in the
interest of getting maximum advantage out of each valve, and hence
minimizing the number that would need to be provided to prevent
lifting of high pressure safety valves 41, it can also be useful to
provide, as via energization of a quick closing time delay
reopening relay, so that the fast valving signal causes control
units 43 to immediately open valves 42 on a feed forward basis
rather than in response to pressure rise, and retain them in open
position for a period long enough for the preprogrammed reductions
in fuel and feed water supply to take full effect, which perhaps
would require a minute or more.
In the U.S. up to now, except at Four Corners and in TVA's newer
stations, only the simplest form of fast valving has been provided
by turbine-generator manufacturers as a response to customers
requests for provision of fast valving as a means of system
stability improvement, namely a system in which intercept valves
only are repositioned momentarily.
In the case of GE what has been offered has conformed to what is
shown in the upper part of FIG. 6 of U.S. Pat. No. 3,601,607 (54)
in which initiation of fast valving depends on the magnitude and
rate of increase of an unbalance between prefault turbine driving
power and generator electrical load under fault conditions.
Actually response to this type of signal tends to be insufficiently
selective (59) and for this reason it can be useful to employ a
fast valving initiation signal provided by a transmission system
responsive control system as a permissive control that would
supplement response to generator power-load unbalance.
However in addition to providing for permissive control of fast
valving of the up to now usually provided type it will normally be
advantageous to preprogram at least some degree of fast reduction
in high pressure turbine steam acceptance plus a related fast
runback of boiler fuel and feed water supply partly as a way to
prevent lifting of reheat pressure safety valves and partly for
reasons of system stability improvement.
Where the fault condition occurs on a radial line or on a weak tie
to other systems, control system 33 can recognize this fact, as
also the prefault load on the line and from this information, if
warranted, generate a fast valving signal that calls for only a
small partial sustained or perhaps no sustained reduction in
turbine driving power, and perhaps for fast full closure of only
one control valve by valve actuator oil dumping, while, if a fault
occurs on a strong tie that is carrying a heavy load, system 33 can
recognize this condition and generate a signal that calls for a
rapid closure of two or even all control valves by means of dump
valve action (59).
Coming now to providing for fast partial reopening of intercept
valves, as a first step it is necessary to provide so that
intercept valve actuator oil dump valves reclose before reopening
can be started, and since it is desirable for intercept valves to
begin to open somewhat in advance of the first forward swing of the
generator rotor, (50) and since time is required in which to bring
about valve acceleration in a reopening direction, it works out
that in situations where generating stations are interconnected by
short lines of extra high voltage, that it can be desirable for
dump valves to reclose in as little as 0.05 to 0.10 seconds
following intercept valve closure.
Present GE dump valves which conform in design to what is shown in
U.S. Pat. No. 3,495,501 (55) and are spring loaded to close, do not
reclose until almost a second after the intercept valve closes.
However Westinghouse dump valves which are power operated to
reclose do so as rapidly as required, and dump type valves also are
commercially available that are equally fast.
Therefore there is nothing to prevent GE from providing sufficient
rapidly acting dump valve means.
Since Westinghouse usually does not control its intercept valve
actuators with servo control, and since GE's servo control is slow
acting, to achieve the objective of rapidly implemented partial
reopening in addition to providing ro rapidly reclose intercept
valve actuator oil dump valves, it is necessary to provide via oil
accumulators so that oil needed to reopen the valves can be
supplied rapidly enough to cause them to open with sufficient
speed, and also provide so that the process of rapid opening
terminates when the valves reopen only part way, as say when they
are 25 to 50 or perhaps 60 percent open (50).
In the matter of limiting the extent of high speed reopening, one
approach would be to provide to admit oil to the valve actuator
cylinders through position operated tapered spool decelerating type
valves that would be arranged to close in response to cam action as
the intercept valve opens.
In another and perhaps simpler approach a metering cylinder can be
interposed between the valve actuator and the accomulator.
FIG. 4 shows a modification of the valve actuator mechanism shown
in FIG. 2 of U.S. Pat. No. 3,495,501 which includes a metering
cylinder 71 which when forced down by admission of oil at the rod
end will cause oil to flow into valve actuator cylinder 70 and push
its piston upward. As shown in the figure to avoid undesirable
impact effects the piston of the cylinder is provided at the bottom
with the same type of decelerating device, taking the form of a
tapered spear protruding from the bottom of the piston, that is
provided at the bottom of the actuator piston.
In FIG. 4, the piston of the metering cylinder is shown at mid
stroke while for ease of inclusion in the diagram the cylinder has
been shown mounted so that its rod end faces upward.
Actually it would appear to be preferable, however, to mount the
cylinder with the rod end down as shown in exterior view in FIG. 5
wherein a pilot operated normally closed two way valve 72 which is
electrically opened by energization of electrically controlled
valve 73 provides a way by which oil stored in accumulator 74 can
cause the piston of metering cylinder 71 to rapidly stroke upward
thereby effecting rapid lifting of the piston of valve actuator
cylinder 70.
Referring further to FIG. 5, 75 is a check valve which serves as a
point at which oil can enter the accumulator from the oil supply
system while 76 is an adaptor that provides for connection of valve
72 to the metering cylinder and that is provided with a bleed
connection to a drain.
Item 77 represents the slow reclosing dump valve shown as item 10
in U.S. Pat. No. 3,495,501, while item 78 represents a duplicate of
valve 72 which can function as an auxiliary fast reclosing dump
valve since it is arranged to by-pass oil around th piston of
cylinder 70, and is activated to open by energization of
electrically controlled valve 79.
By reference to FIG. 1 of U.S. Pat. No. 3,495,501 it will be noted
that in FIG. 5 the intercept valve assembly is being viewed from
that side at which steam enters the valve, which is the reason why
oil return line 80 of FIG. 4, which is item 9 of FIG. 2 of U.S.
Pat. No. 3,495,501, is not visible.
The concept behind the showing of an auxiliary dump valve is that
if it did not turn out to be easy to modify the valve described in
U.S. Pat. No. 3,495,501 so as to render it fast reclosing, this
valve could still be retained in use as a way to provide overspeed
protection, while employment of fast reclosing as well as fast
opening dump valve 78 would be effected primarily as a means of
implementing fast valving, though it could also be used to provide
a redundant means of closing the intercept valve in response to a
condition of overspeed.
In the writers concept valves 72 and 78 could comprise a
commercially available very rapidly acting valve that has been
widely used for controlling the operation of die casting
machinery.
However despite its record of successful use the turbine producer
could well prefer to use his own time tried valve as a way to
perform the very important function of protection against
overspeed, which being the case, the provision of an auxiliary dump
valve for control of fast valving which could also function as a
redundant means of initiating valve closure in response to
overspeed conditions would serve the purposes of fast valving yet
could in no way serve to degrade reliability of overspeed
protection.
Returning now to FIG. 5, control system 81 is arranged to control
the position of valves 73, 77 and 79 through electrical connections
shown as dashed lines.
In service use the accumulator containing its normal complement of
oil and the piston of the metering cylinder 71 is up against the
rod end of the cylinder so that the piston rod is fully extended
downward. Also electrically controlled valves 73 and 79 are
deenergized and valves 72 and 78 closed.
It is provided that when an event occurs that results in a fast
valving signal input to control system 81, valve 79 is energized,
which causes valve 78 to open with the effect that the intercept
valve closes.
After alowing time for closure to take place, and optionally also
ensuring that it did take place by means of a feeler switch which
is not shown, the control system energizes valve 73 which causes
valve 72 to open whereupon the piston of metering cylinder 71
strokes upward and forces the piston of cylinder 70 to rise part
way.
Next after a delay period valve 73 is deenergized which causes
valve 72 to close and because oil can slowly drain out of adaptor
76 via its drain connection, the piston of the metering cylinder
drops down at a rate governed by the rate of discharge via the
drain, which is made low enough so that there is no problem of
impact when the piston comes to rest at the end of its stroke, at
which stage the valving cycle is complete.
One incidental but not unimportant advantage that the metering
cylinder offers relative to decelerating type valve, that may be
worthy of note, is that by providing a supplementary push button
control that would act to energize electrically controlled valve 73
the metering cylinder can be from time to time stroked under normal
load conditions, and by providing the accumulator with a pressure
gauge and observing the pressure drop when stroking takes place it
could be easily determined whether or not the accumulator contains
its normal content of nitrogen and if it did not, provide to add
nitrogen.
Because electrically controlled valves 73 and 79 need to be fast
acting, use of an alternating current type of solenoid valve would
offer advantages, which however would be in part offset by the need
to supply power to these valves by means of an inverter which would
take its power from a storage battery. One solution to this problem
would be to employ a dc solenoid valve having laminated magnetic
components as a way to avoid eddy currents which develop in solid
type solenoid plungers and slow down valve operation.
Where intercept valves are of plug type as is customary in fossil
fuel type turbines it works out that typically 8 to 10 percent
stroke will open the valve enough to pass 35 percent of full load
steam with reheat pressure at the value that applies at full load,
and that around 13 to 15 percent will supply 60 percent, which
means that only a relatively small volume of oil is needed when
fast partial valve opening is planned, which implies in turn need
to employ only a short metering cylinder and a relatively small
accumulator. Also because of the small amount of valve stroking
needed, where the point applies that GE intercept valves are
provided with servo valves, use of a metering cylinder could be
dispensed with if servo controlled stroking rate were increased
from their present usual value of 10 seconds full stroke to around
21/2 seconds full stroke.
Where intercept valves are not provided with means of servo control
the metering cylinder approach would appear to provide a relatively
simple solution to the problem of limiting extent of high speed
reopening.
So far what has been said on the subject of control valve operation
has had relation to U.S. units having partial admission type high
pressure turbines which also typically do not have provision for
rapid enough stroking of valves under servo control to serve
effectively as a way to bring about a reduction of high pressure
turbine steam acceptance that will serve the needs of fast
valving.
In cases where high pressure turbines are not equipped for partial
admission and provide fast enough control valve stroking under
servo control to sufficiently limit turbine speed under entire loss
of load, as applies in the case of Brown Boveri units, rate of
valve closure, when fast valving is initiated for purposes of
system stability improvement, has turned out to be not too low to
afford stability improvement based on the fact that the Brown
Boveri units in question have had higher specific inertias then
steam-electric units of U.S. manufacture.
With servo control available it is possible to fully or nearly
fully close control valves and completely or nearly completely
close intercept valves, and to also thereafter reopen both types of
valves part way, provided that oil accumulators are made use of as
a way to ensure sufficiently rapid valve reopening.
This method of accomplishing fast valving has been provided for in
the case of unit No. 2 of TVA's Cumberland station, in which a 1300
MW cross compound Brown Boveri turbine is supplied with steam by a
Babcock & Wilcox oncethrough boiler, the general arrangement
being as shown in FIG. 2 wherein like identifying numbers have like
meanings to identifying numbers of FIG. 1.
Numbers not shown in FIG. 1 comprise primary and secondage
superheaters 14 and 15, fly ball type turbine speed sensor 28,
superheater by-pass valve 47, with is control unit 48, flash tank
49 and valves 50 which are arranged to open in response to an
excess of flash tank pressure.
From the standpoint of fast valving the important feature shown in
FIG. 2 is the nature of the superheater by-pass valves provided as
an element of the steam generator, which comprises an array of fast
acting air operated valves which, when opened, allow steam to flow
to the condenser via the flash tank, and which, taken together,
have proved to have enough flow capacity to prevent lifting of high
pressure safety valves even in the event of a turbine trip-off
taking place at full load. (37).
The fact that these valves both offer this much steam acceptance
capability, plus the fact that, unlike superheater by-pass valves
provided by the two other leading U.S. producers of the power
station boilers, they are fast acting, implies that there is no
objection to employing full closing of all control valves, and
thereafter reopening part way under servo control over a period of
up to 10 seconds which represents the time required for control
valves of GE electrohydraulic turbine control units to reopen full
stroke.
This built in by-pass capability not only affords something in the
way of an advantage as regards opportunity for system stability
improvement, but, more important, eliminates need to purchase and
install power operated relief valves at added cost where provision
for fast valving is being made.
When it comes to how to provide so that B & W's superheater
by-pass valves are caused to open .[.when fast valving is
involved,.]. when fast valving is invoked at Cumberland, B &
W's initial approach will be to provide so that they open without
delay in response to development of a predetermined increase in
pressure within the superheater system and reclose progressively as
pressure falls.
An alternate approach would be to preprogram a process of valve
opening that would be designed to prevent a rise in, or to somewhat
reduce pressure, and that would be followed by a process of
progressive valve reclosing as pressure dropped below a preset
value.
Referring now to FIG. 3, which represents a nuclear steam-electric
installation, steam supplied by nuclear steam supply souce (NSSS)
13 which could be of either the pressurized water reactor (PWR) or
boiling water reactor (BWR) type flows principally into high
pressure turbine 18 while some is diverted to he steam reheat coils
located within moisture separator reheater (MSR) 20.
In the figure there is a line from the moisture separator reheater
which drains to drain tank 60, from which drain water flows
normally through check vlve 61 and drain tank level responsive
valve 63 into the low pressure feed water system 3, but can also
flow to the condenser through check valve 62 and drain tank level
responsive valve 64.
Whereas only one MSR, and only one drain tank 60 and associated
valving 61 through 64 is shown, it is to be understood that in
actuality there are two MSRs each with its own drain tank and set
of associated valves for each low pressure turbine, or in the
installation shown in FIG. 3 a total of 6 MSRs, 6 drain tanks and 6
sets of valves.
Steam that passes through the MSRs enters 3 low pressure turbines
24 via 6 pairs of stop and intercept valves 21 and 22
respectively.
In PWRs item 40 represents a high pressure safety valve that
discharges steam to atmosphere while in BWRs it represents a safety
valve that discharges direct to the suppression chamber of the
reactor or the condenser.
Similarly, in the case of PWRs safety valves 45 and 46 are arranged
to discharge low pressure steam to atmosphere, and in the case of
BWRs to the condenser.
Items 50 represent groups of by-pass valves that are arranged to
open in response to excess steam pressure ahead of the turbine,
such as can develop when the steam acceptance of high pressure
turbine 18 is reduced by closure of control valves 17.
In the case of PWR reactors of Westinghouse type at full load steam
delivery pressure falls well below pressure at no load and it
results that a sufficiently brief momentary full closure of control
valves 17 plus a sustained 50 percent reduction in high pressure
turbine steam acceptance will not lift safety valves 40.
On the other hand it is to be understood that if the NSSS is of BWR
type, the by-pass capability of valves 50 limits, to the capacity
of the by-pass system, the extent of even only momentary reduction
in high pressure turbine steam acceptance that can be tolerated
without scramming the reactor.
For the above reasons and because by-pass capability is expensive,
in the case of those BWRs which do not have 100 percent by-pass
capability, which is the usual situation, and assuming partial
admission units are involved, it can be essential to rapidly fully
close no more than two and in some cases only one control
valve.
In the case of nuclear turbines Westinghouse units employ butterfly
type intercept valves which have the advantage that in closing they
operate to very rapidly reduce low pressure turbine steam
acceptance, but the disadvantage that when opened conventionally at
a steady rate over a period of 5 seconds reacceptance of steam by
the low pressure turbine is delayed for over two seconds which is
disadvantageous and therefore it is important to provide via fast
closing dump valves, accumulators and metering cylinders or perhaps
cam operated decelerating valves so that the valves rapidly reopen
part way, as in the range 25 to 50 percent on a flow basis within
1/2 second after the peak of the generator rotor first forward
swing.
How this could be accomplished would differ in detail only from
what is shown in FIGS. 4 and 5.
Whereas in the case of both fossil fuel and nuclear steam turbines
the desirability of making provision for fast partial reopening of
intercept valves has been stressed it could also apply that
providing for fast partial reopening of control valves could prove
advantageous in situations where it might serve to limit
requirements as to need for additional steam by-pass
capability.
In the area of problems that could arise in application of fast
turbine valving to nuclear steam electric installations the GE has
cautioned that fast valving, even of the type that employs only
momentary intercept valve closure, could give rise to difficulties
in the way of malfunction of moisture separator reheater drain
systems due to the mild form of MSR depressurization that takes
place when intercept valves reopen after at first initially
closing.
To the extent that such a problem exists it would tend to be
intensified when control valves are rapidly closed.
However, there is evidence which suggests that, with proper design
of MSRs and their drain systems, rapid depressurization has not and
in the case of fast valving wll not cause a problem of
consequence.
Tests will be needed to clarify this point.
If, following tests, a problem remained that could not be readily
solved one solution would be to provide to fully close both the
turbine's control and intercept valves and after closure rapidly
open them both to a point at which the control valve has reached
its preprogrammed new sustained position and the intercept valve
has reached an equally open position on a flow basis, and providing
thereafter to only slowly fully reopen the intercept valves under
servo and/or rate of oil flow control, while in the case of PWR
type reactors or at any rate in the case of Westinghouse PWRs this
would not involve a need to provide added steam by-pass
capability.
On the other hand it would represent a costly approach where BWR
reactors were planned for use because it would require providing
one hundred percent by-pass capability.
However in the case of BWRs, and for that matter also in the case
of PWRs, an alternate approach appears to be feasible, due to the
fact that it is claimed that experience to .[.data.]. .Iadd.date
.Iaddend.has shown that, presumably due to the cleanliness of the
steam and its low discharge velocity, low pressure safety valves of
nuclear installations have not leaked following discharge of steam,
whether or not they are of the pilot operated type employing teflon
O-rings which are widely employed in Westinghouse PWR
installations, or of the spring loaded type used by GE in BWR and
also in PWR installations.
To the extent that this claim can be relied on as a guide to the
future, the point would apply that it is feasible to control
turbine driving power in the period following the generator rotor
first forward swing, by merely providing to suitably control
intercept valve reopening (52) during the entire period during
which steam generation within the reactor is being reduced, and
rely on discharge of steam through low pressure spring loaded
safety valves to limit rise in MSR pressure.
Moreover by providing to lift these valves in response to
activation of electrically controlled air operated lift cylinders
(51) with the use of pressure switches which could be preprogrammed
to provide control only when fast valving has been .[.involved.].
.Iadd.invoked.Iaddend., the valves could be employed as a way to
hold MSR pressure constant during the entire fast valving process,
thereby avoiding need for concern as to the behavior of MSR drain
systems.
Furthermore it might also prove feasible to extend this concept to
fossil fuel installations.
In the fossil fuel case the point would apply that experience has
shown that reheat pressure safety valves are less likely to be
damaged by discharge of steam than are high pressure types, due
presumably to the lower velocity on steam discharge.
Also there is reason to believe that providing to lift safety
valves with an air cylinder, rather than merely allowing them to
lift on their own in response to increase in steam pressure, also
can be expected to minimize damage effects.
Therefore, and especially if steps are taken so that the boiler,
superheater and reheater are kept in a clean condition (63) the
approach of providing for control of driving power in the period
following the generator rotor first forward swing via control of
rate of .Iadd.intercept valve .Iaddend.reopening could represent a
workable procedure.
When it comes to how to regulate intercept valve reopening, there
would remain the desirability of first rapidly opening the valves
part way, and then proceeding more slowly.
When it comes to control of position in the period following
initial fast partial reopening, the point applies that it is well
within the skill of control system designers to provide, as with
the aid of flow control devices, and/or servo systems which could
be equipped with a time varying control input that could comprise a
motor driven cam that varied the position of a core in a linear
differential transformer, so as to effect preprogrammed processes
of intercept valve reopening, such that following an initial rapid
drop during the period of generator rotor first forward swing,
turbine driving power would be restored to a new preprogrammed
sustained value, which in the case of fossil fuel installations
would preferably be selected to be somewhere in the range of 60 to
90 percent of full load value, but in the case of PWR and BWR
nuclear installations, could cover a wider range, since thermal
fatigue effects represent a minor factor in the life of nuclear
turbines of these types, due to low value of steam temperature.
One point that has so far not been touched on relates to the fact
that it is not unusual for steam driven boiler feed pumps to
receive their steam from an extraction point of an intermediate
pressure turbine, in which case the turbine steam supply from this
source is downstream of the intercept valves and will be much
reduced, if it does not momentarily disappear, when intercept
valves are rapidly fully closed as an aspect of fast turbine
valving.
This will result in a process of slowing down of the turbine which
will operate to reduce rate of feed water supply more rapidly than
the preprogrammed extent of reduction of heat release within the
steam generator, but the speed with which this occurs will be
governed by the combined specific inertia of the turbine and pump,
and, especially if intercept valves are rapidly reopened part way,
it has so far appeared to experts in the design of fossil fuel
steam generators, that the momentary slowing down that would be
experienced would not be consequential as regards effect on the
steam generator.
Moreover, in any case, turbines that, at over a predetermined load,
accept steam from a point downstream of the intercept valve
commonly are provided with means to accept steam either or both
from the cold side of the reheaters or the high pressure steam
header at light loads.
Normally separate steam chests are provided as a way to allow
transfer to one or other of these steam sources and it could
readily be provided, and may prove desirable, to effect transfer as
a preprogrammed rapidly executed step that would be put into effect
in response to a fast valving signal.
Similarly, if in the case of nuclear units, in some cases, boiler
feed pump turbines draw steam from a point downstream of the
intercept valve, provision can be made to rapidly transfer to the
main high pressure steam supply in response to a fast valving
signal.
It is believed that the foregoing has served the purpose of showing
how it is feasible to preprogram fast valving procedures, involving
sustained step reductions in turbine driving power which will well
serve the purposes of power system designers when it comes to
providing ways to minimize generation station first cost through
avoiding need to install redundant circuit breakers, and also as a
way to avoid need to construct redundant lines (36).
However to complete the picture it is necessary to provide so that
processes of diversion of steam to atmosphere, or to the condenser,
that need to be employed as a way to prevent discharge of steam
through high pressure safety valves will be terminated without too
long a delay.
Actually this is easy enough to accomplish by merely providing to
simultaneously rapidly reduce heat release within, and feedwater
supply to, the steam generator on a preprogrammed basis, with
provision to temporarily override normally utilized feed back type
control systems.
Also as matters stand providing this type of control is already
well within the skill of designers of steam generator control
systems, whether of types that are used in fossil fuel or nuclear
steam generators. Thus systems for effecting fossil fuel steam
generator runback, to the extent of 50 percent, accomplished in a
matter of 30 seconds (61, 62), have been provided by steam
generator producers, to handle contingencies such, for example, as
a suddenly occurring outage of one of two parallel operating steam
turbine driven feed water pumps, while it also appears that, even
in coal fired fossil fuel installations, speeding up the process
can be carried out so as to provide a 40 percent runback in 10
seconds, although attaining this speed apparently has not proved to
be critically needed as a way to avoid development of excess
temperature of superheater components (62), and provision for 25
percent runback of BWR nuclear units in a matter of 25 to 50
seconds, and of PWR units in 2 to 4 minutes, is typically
feasible.
Based on the foregoing the essential feature of the present
invention is viewed as comprising an explanation of how it is
possible to provide to rapidly bring into effect preprogrammed
control processes directed to effecting sustained partial as well
as momentary reduction of turbine driving power, and do so with the
use of techniques and equipment that are essentially already
available, except to the extent that certain minor changes in
equipment for controlling the rapid positioning of turbine valves
represent features that are necessary to realization of full
potentialities.
Moreover it is easily possible and will generally be useful to
provide, within turbine and steam generator control system 39, a
plurality of preprogrammed matched turbine and steam generator
control processes, and to further provide so that, when an event
occurs that sufficiently endangers system stability to require
initiation of fast valving, generating station system responsive
control system 33 will not only initiate it but will perform, in a
preprogrammed way, the function of selecting for initiation one
particular pair of control processes from among the available
plurality of matched pairs, as for example by sending to control
system 39 an input that causes initiation of a sustained reduction
of driving power of 10 percent when a fault occurs on line 1, but
perhaps one of 20 percent if on line 2, and perhaps one of 40
percent if, as evaluated by what is shown in U.S. Pat. No.
3,657,552, it is expected that both lines will open due to delay in
fault clearance, or if one line is already open and the other open,
and perhaps also initiate a 40 percent reduction when a fault
occurs on line 3.
Also it is possible to provide as per what is shown in U.S. Pat.
No. 26,571, so that in case of unsuccessful reclosure on a faulted
line, the initially selected pair of control processes are modified
in a preprogrammed way, or so that the initially selected pair is
modified if reclosure is successful.
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70 TP 147-PWR, Vo. Pas-90, No. 1, Jan/Feb 1971, pp. 1-10.
29. C. Concordia and P. G. Brown, "Effects of trends in large steam
turbine driven generator parameters on power system stability,"
IEEE Paper No. 71 TP 74-PWR, pp. 2211-2218.
30. H. E. Lokay and P. O. Thoits, "Effects of future
turbine-generator characteristics on transient stability," IEEE
Transactions on Power Apparatus and Systems, Vol. 90/1971, Paper 71
TP 75-PWR, pp. 2427-2435.
31. R. H. Park, U.S. Pat. No. 3,515,893, June 2, 1970, "Method of
improving the stability of interconnected power systems."
32. R. H. Park, U.S. Pat. No. 27,842
33. R. H. Park, "Improved reliability of bulk power supply by fast
load control," presented at American Power Conference Apr. 24,
1968.
34. cf Ref. 31 - column 19, para. 2
35. W. Trassl, "Safe cycling of high-pressure steam turbines,
"Proc. American Power Conf., vol. 31, pp. 306-313, 1969.
36. E. Floyd Thomas et al, "Preliminary operation of TVA's
Cumberland Steam Plant," presented at American Power Conference,
Chicago, May 1973.
37. O. W. Durrant and R. P. Siegried, "Operation and control of
once-through boilers during electric power system emergencies,"
presented to IEEE Section Meeting, Dallas, Texas, Oct. 21,
1969.
38. Reference 50 of reference 33.
39. P. J. Martin and Ludwig E. Holly, "Bypass stations for better
coordination between steam turbine and steam generator operation,"
Am. Power Con. 5/8/73.
40. Cushing et al, "Fast valving as an aid to power system
transient stability and prompt resynchronization and rapid reload
after full load rejection," IEEE Paper 71 TP 705-PWR.
41. Reference 24, p. 442, column 1, para. 1.
42. Reference 29, p. 2211, column 2, para. 4.
43. Reference 27, p. 42, column 2, para. 2.
44. R. H. Park, "Fast turbine valving," paper T72 635-1, IEEE Trans
on Power Apparatus & Systems, Vol 92 pp. 1065-73
45. Reference 44, p. 1069, column 1.
46. R. H. Park, U.S. Pat. No. 3,657,552, Apr. 18, 1972.
47. R. H. Park, discussion of reference 29, p. 2217, column 1,
para. 5.
48. R. H. Park, discussion of reference 40, p. 1635, column 2, para
8.
49. A. C. Sullivan and F. J. Evans, "Some model experiments in fast
valving to improve transient stability," IEEE Paper No. C. 72
242-1.
50. Reference 44, p. 1067, column 1, para. 2.
51. Reference 44, p. 1066, column 2, para. 9 and 10.
52. Reference 31, column 19, para. 6.
53. Leon K. Kirchmayer, "Economic Control of Interconnected
Systems," John Wiley & Sons, Inc., Publishers, New York,
1959.
54. F. P. De Mello et al, U.S. Pat. No. 3,601,617, Aug. 24,
1971.
55. J. Kure-Jensen, U.S. Pat. No. 3,495,501, Feb. 17, 1970.
56. Reference 44, p. 1066, column 2, para. 3.
57. Reference 44, p. 1068, column 1, para. 11, through column 2,
para. 2.
58. Reference 44, p. 1067, column 2, paras. 3, 4, 5.
59. Reference 44, p. 1071, column 2, H. R. Stewart discussion of
reference 44, and p. 1071-1073, R. H. Park response.
60. Reference 44, p. 1067, column 1, para. 9 and 10.
61. O. W. Durrant, "Operation and control of once-through boilers
during electric power system emergencies," 1970 Proceedings of the
ISA, pp. 1-14.
62. F. H. Fenton, Jr., and J. V. Pigford, "Rapid response and
maneuverability are obtainable from supercritical plants," 1970
Proceedings of the ISA, pp. 15-26.
63. Reference 44, p. 1069, column 2, para. 3.
64. R. H. Park, "Relay and Control Techniques Used to Activate Fast
Steam Turbine Valving for System Stability Improvement" Minutes of
Meeting of Relay Committee, May 23-4, 1974, Engineering Section,
Pennsylvania Electric Association.
65. K. H. Bieber, "Assured Power Supply With Modern Flexible
Generating Units and Bypass Systems Operating At Variable Pressure
in A West German Utility System," IEEE Paper No. 71 CP 708-PWR.
66. CIGRE Committee Report, "The Electro-Hydraulic Governing Of
Large Steam Turbines," ELECTRA, No. 33, pp. 91, 114.
67. A. J. Smith and George Platt, "A Method for Correcting
Turbine-Generator Sudden Load Loss," Instrument Society of America,
"Instrumentation in the Power Industry," Vol 14, 1971.
68. R. H. Park, U.S. Pat. No. 3,849,666, Nov. 19, 1974.
Further references cited herein comprise
69. W. Goodbrand and E. D. Holdup, "Recent load rejection testing
of large steam generator-turbine generator units and an analysis of
a major disturbance on the Ontario Hydro system," presented at the
IEEE-ASME Joint Power Generator Conf. Sept. 1971.
70. "Sulzer safety systems for steam generators", Sulzer News no.
1/73, a publication of Sulzer Bros. Boiler and Nuclear Dept.,
Winterthur, Switzerland.
71. "Steam Conversion in Steam Distributing Systems" Braunkohle,
Warme and Energie, Vol. 12, No. 9, Sept. 1960, pp. 438 to 444.
72. Reference 44, page 1069, material under heading "Sudden Partial
Loss of Area Export Load."
Referring now to FIG. 6, there is shown therein the steam electric
installation of FIG. 1, modified by the inclusion of a by-pass
system which is adapted to discharge steam from the hot reheat line
81 to condenser 1, and assumed, also, to incorporate provision for
servo control of the position of the turbine's intercept valves,
which valves, also, are further assumed to be of a type that is
adapted to withstand long duration service in a partially open
position.
The by-pass system consists of one or more valves 82 which connect
to one or more desuperheaters 83 which in turn connect to the
condenser through one or more steam lines 84.
Valve 85 controls supply of water to the desuperheater, received
via water line 86, which, as shown, makes connection to the water
line that joins boiler feed pump 5 to high pressure feed water
heaters 8. However the use of an alternate source of desuperheating
water is not excluded.
By-pass control system 87, and desuperheating water flow control
unit 88, can comprise equipment of types commonly used in
Continental European once through boiler steam electric
installations (70,71).
As explained in reference 70, the control system of valves of this
type as produced by Sulzer Brothers, when used in fossil fuel
installations, causes them to open on a flow modulating basis
whenever hot reheat line steam pressure exceeds a first set point
which follows continuously and automatically the actual operating
pressure, and causes fast full valve opening when reheater pressure
exceeds a second set point which also continuously and
automatically follows the actual operating pressure, while water
flow control unit 88 is arranged to respond to steam temperature
downstream of the desuperheater as evaluated with a steam
temperature sensor, which is not shown in the drawing.
In the Siemens system desuperheating water is admitted into the
valve body itself (71).
In both Sulzer and Siemens systems, as probably in other competing
versions, by-pass valves are equipped with hydraulic operators
which are capable of ensuring that rise of steam pressure within
the hot reheat line is sufficiently restricted to prevent opening
of reheat pressure safety valves when the steam acceptance of the
low pressure turbine is reduced in a fraction of a second by an
amount that does not exceed the flow capacity of the valves.
Apparently, also, the valves of by-pass systems used extensively in
Germany, and also rather generally in continental Europe, are not
subject to steam leakage in an amount that represents a serious
problem, since, per reference 66, practically all thermal power
plants in continental Europe are equipped with HP and LP by-pass
systems (cf ref. 66 section 5.5 p. 107).
However, in any case, to the extent that leakage should turn out to
be a problem it can, if it is serious enough, be corrected by valve
maintainance, which can be carried out without scheduling a
shutdown if shut off valves are provided on both sides of the
valve.
Referring to FIG. 6 when turbine control system 39 receives a fast
valving signal that has been generated in fast valving signal
generator 33.Iadd., it can be provided for that .Iaddend.there will
come into effect preprogrammed processes of
1. intercept valve closure which are fast enough and sufficient in
extent to have a favorable effect on generator rotor first swing
stability, and preferably take the form of full closure effected in
1/4 second or less,
2. subsequent reopening of some or all intercept valves to a
partially open position with reopening preferably initiated
somewhat in advance of the first forward swing of the generator
rotor, and carried to completion within a fraction of a second
following the peak of that swing,
coupled with
3. preprogrammed servo valve implemented retention of partially
opened intercept valves in, or substantially in, the preprogrammed
position that they attained in their rapidly executed reopening
process,
with which techniques the intercept valves assume and retain a
partially opened position at the end of a preprogrammed
repositioning cycle, until such time as an election is made to
further reopen them.
With use of a by-pass system that responds to reheat pressure, such
as shown in FIG. 6, when the by-pass system will pass, at rated
full load hot reheat line pressure, x percent of intermediate
pressure steam acceptance at rated full load, it is possible to
fully close intercept valves at top speed, in response to a fast
valving signal, and partially reopen at or about the instant of
generator rotor first forward swing, to a point at which the valves
will pass 100-x percent of rated full load steam flow, and yet
avoid lifting of reheat pressure safety valves.
Thus, in detail, assuming by way of example that x=50, and that, as
a case in point, the rated full load combined driving power of the
intermediate and low pressure turbines is 70 percent of rated load,
and taking it as a sufficient approximation that turbine driving
power is proportional to steam flow, it would be possible to reduce
low pressure turbine driving power, on a sustained basis, by 35
percent of rated full load value, by restricting the extent of
intercept valve lifting to 50 percent on a flow basis, and do so
without initiating any process of closure of control valves or need
to reduce rate of steam generation, or to be concerned about the
temperature of the reheater.
Also since pressure ahead of the high pressure turbine will not
change, and reheater pressure will change only slightly, total
turbine driving power will remain substantially fixed at, 100-35=65
percent of rated full load value until such time as a decision is
made to increase driving power, which can be accomplished by merely
further opening the turbine's intercept valves.
There would also be opportunity to close control valves (17), in
response to the fast valving signal, at top speed, and fully reopen
on a preprogrammed basis, at, or about, or prior to the time of
peaking of the first forward swing of the generator rotor, and, if
high pressure safety valves are not set too low, their lifting
would be avoided, this tending especially to be true if there were
available one or more power operated relief valves 42.
At the same time there would be the option of reducing rate of
steam generation subsequent to completion of processes of
preprogrammed fast valving, whereby to allow partial closure of
control valves and more complete opening of intercept valves, as a
way to minimize turbine thermal fatigue effects, if it turned out
that such effects were great enough to warrant.
Evidently, by choosing x=60 turbine driving power could be reduced
to 100-0.7.times.60 or 58 percent while with x=40 the figure would
be 72 percent, and with x=30, 79 percent.
Also, to the extent that there was capacity to discharge steam to
atmosphere, via valves 42, or through other valves that would
discharge to the condenser, or, as in continental European
practice, to the cold reheat line (cf refs. 35 and 65), sustained
partial control valve closure could be made use of as a way to
minimize needed capacity of the low pressure by-pass sytem, and to
minimize thermal fatigue effects within the intermediate pressure
turbine.
Also, if by-passing of high pressure steam was accomplished with a
continental Europen type desuperheating by-pass system that
diverted steam from a point ahead of the turbine to the cold reheat
line, there would be no requirement to adjust rate of steam
generation since the reheater would be prevented from
overheating.
Further, although the control scheme just set forth, was
illustrated in the context of FIG. 1, it will be readily
appreciated that it is equally capable of use as a control system
modification that could apply to the steam electric installations
of FIGS. 2 and 3, so long as the intercept valves are servo
controlled and therefore capable of being held fixed in a partially
open position.
In relation to all of the foregoing, it is to be understood that,
with the benefit of oil accumulators, fast partial reopening of
intercept valves is capable of accomplishment, either with use of
high capacity servo valves, or where size of servos is inadequate,
with the use either of the metering cylinder system illustrated in
FIGS. 4 and 5, or with the aid of cam operated decelerating type
valves.
Where, as matters stand, in PWR nuclear steam electric
installations, it has become the custom to provide, as a minimum,
45 percent high pressure steam by-pass capability, it would not be
necessary to employ a low pressure steam by-pass system, since, as
there is no problem of overheating of reheaters, nor, since fast
valving would be seldom invoked, any significant problem of thermal
fatigue, and since, in a PWR installation, momentary closure of
control valves does not induce safety valve lifting, there is also
no problem in effecting a combination of preprogrammed fast
intercept valve closure followed by partial reopening, coupled with
simultaneously executed preprogrammed
a. fast full control valve closure followed by fast partial
reopening, or
b. merely fast partial control valve closure, which closure process
can be so carried out as to limit the extent of rise in MSR
pressure, and avoid operation of safety valves.
When it comes to either PWR or BWR type nuclear installations,
there is an advantage in avoiding reduction of MSR pressure with a
view to eliminating hazard of instability of MSR drain systems.
Thus referring to FIG. 3, to achieve this result in a PWR
installation, care would be taken that the process of control valve
repositioning would be so programmed that up to the point that the
intercept valves .[.(22).]. .Iadd.22 .Iaddend.had reached their
preprogrammed final sustained partially open position, the supply
of steam to the moisture separator reheater .[.(20).]. .Iadd.20
.Iaddend.would exceed the amount leaving it, with the net effect
that MSR pressure would at first rise rather than fall.
However, at the same time, control valves .[.(17).]. .Iadd.17
.Iaddend.would preferably be fully closed and partly reopened, at
somewhat less speed than would apply to the intercept valves
.[.(22).]. .Iadd.22.Iaddend., as a way to minimize the extent of
MSR pressure rise that takes place up to the point of stabilization
of the turbine's intercept valves in their preprogrammed partially
reopened position.
Also the option would be available of providing the turbine's
control system with an MSR pressure input which input would be
arranged so as to cause the control system to hold MSR pressure
constant.
As previously noted, in the case of BWR type installations, it is
desirable to dispense with preprogrammed control valve closure, in
view of the fact that reduction of high pressure turbine steam
acceptance operates to increase reactor pressure, which, if
occurring rapidly, other than in small amount, will cause reactor
scram.
Further, it is desirable to minimize MSR pressure changes, not only
to avoid MSR drain system transients, but also to avoid inducing
changes in high pressure turbine steam acceptance.
Therefore the desirability of making use of a servo controlled low
pressure by-pass system that responds to rise in MSR pressure is
indicated.
In .[.BNR.]. .Iadd.BWR .Iaddend.installations holding control valve
position constant would have the effect that reduction of high
pressure turbine steam acceptance would be confined to that induced
by increase in pressure ahead of the low pressure turbine, which
would be held small by the low pressure by-pass system, while, also
such decrease in high pressure turbine steam acceptance as would be
experienced, would be dealt with through the working of the
reactor's steam pressure rise responsive feed back type control
system, which regulates the position of by-pass valves that
discharge high pressure steam to the condenser, and which
automatically comes into play when high pressure turbine steam
acceptance decreases, and operates successfully to prevent reactor
scram if rate and extent of pressure change is not excessive.
While the low pressure by-pass control system shown in FIG. 6
offers the advantage that it holds pressure ahead of intercept
valves constant, independent of the extent of preprogrammed, or
subsequent further, valve reopening, the point applies that, in the
case of fossil fuel and HTGR nuclear installations, it would also
be possible to dispense with the modulating aspect of the system,
and arrange merely to fully open valve or valves 82 when fast
valving is .[.involved,.]. .Iadd.invoked, .Iaddend.and to provide
so that the capacity of the valves was suitably coordinated with
the preprogrammed extent of intercept valve partial reopening, or
vice versa, in such manner as to hold hot reheat line pressure
constant or cause it to somewhat decrease.
If there were several valves 82 there could be election to open a
variable number of them, and in any given case, provide for
coordination of extent of preprogrammed intercept valve
reopening.
It would be also possible to utilize as by-pass valves 82 air
lifted spring loaded valves that would preferably be equipped with
shutoff valves on either side to avoid need for a unit shut down
when maintenance was required.
Shut-off valves can advantageously be of the gate type while the
valve that stands between the by-pass valve and the hot reheat line
would preferably be provided with a split gate having a connection
through the valve body to the space between the two halves of the
split gate, which feature offers the advantage that it makes
possible entire prevention of leakage of steam through the valve
during maintenance periods, by, in such periods, employing the
expedient of pressurizing the space between the gates with high
pressure nitrogen.
In another approach to controlling reheat line pressure it would be
possible to arrange to open and close some of reheat pressure
valves 82 in response to steam pressure, whereby to employ the
valves in question to effect on-off type pressure control.
Where reference has been made to increase in hot reheat line and
MSR pressure when fast valving is invoked, and a low-pressure
by-pass system is employed that is arranged to modulate on a feed
back basis in response to pressure ahead of the system, or if
resort is had to the on-off type control, the point applies that
control action is not required until fast valving is initiated,
which means that the set points of the controls can be made such as
to minimize pressure rise when the by-pass system comes into effect
in response to a fast valving signal.
Where, as in FIG. 3, PWR and BWR nuclear installations incorporate
three low pressure turbines it is possible, as an alternate to fast
closure and partial reopening of all intercept valves (22), to
first close all valves, but fast reopen the valves of two low
pressure turbines while retaining the valves of the third unit in
closed position.
This technique would offer the advantage of allowing .[.extension
of.]. application of the practice of sustained reduction of driving
power of low pressure turbines of Westinghouse manufacture used in
PWR and BWR nuclear installations, in which servo valve control of
intercept valves are not provided.
Also, when, as in the case of GE turbines, there has been, or would
be, objection to employing fast closure of intercept valves of PWR
and BWR nuclear installation turbines, where this would be followed
by fast reopening against full MSR pressure, it would be feasible,
instead to provide for fast closing, and subsequently to hold
closed the intercept valves of one unit while, where needed,
bringing about improvement of generator rotor first swing, or first
and second swing stability with the benefit of a braking
resistor.
This would leave the problem of how to proceed to reopen the valves
of the unit that was valved down. However, this could be handled by
partly unloading the turbine, as during nighttime system light load
operation, at which point there would be no harm in initiating the
reopening process.
Also the above procedures could be extended to fast valving down
three low pressure units and restoring power to only one, or to
fast valving down and holding two units in unloaded condition, and
the concepts involved could also be utilized when there were two
instead of three low pressure turbines, or if there should ever be
as many as four or more.
There are thus several ways and techniques of implementing the
present invention, preferred forms of which vary in some degree in
dependence on the type of turbine steam supply source as well as on
the nature of the turbine and its control system.
While the present invention has been described in conjunction with
preferred embodiments, it is to be understood that modifications
and variations may be resorted to without departing from the spirit
and scope of the invention as those skilled in the art will readily
understand. Such modifications and variations are considered to be
within the purview and scope of the invention and the appended
claims.
In addition it could be in order to note that the point applies
that concepts of the present invention can be usefully applied as
ways to implement processes of fast valving for the purpose of
reducing the extent of turbine overspeeding in the event of partial
loss of load, such as can occur in the event of a system breakup
that causes system electrical islands to form which contain turbine
driven generators, and in which the islanding process has resulted
in a loss of islanded area load, either at once, or as a result of
the influence of load shedding internal to the area (72).
CLAIM TERMINOLOGY
The basic approach to improvement of power system stability that
underlies what is set forth in the present application is to
provide and utilize means of responding to suddenly occurring
events that jeopardize power system stability by sufficiently
rapidly reducing the driving power of at least one power system
generator prime mover.
To accomplish this result delay in initiating valve closure and
time to close, once closure is begun, are preferably made such that
valves close fully in 1/4 second or less.
Going back into history, in the Staege patent (1) wording of claim
2 is "2. In a power-transmission system, a power circuit, a
generator connected to said power circuit, a prime mover for
driving said generator, and means for increasing the stability of
said transmission system comprising means operative upon abnormal
power-circuit current for reducing the flow of motive fluid to said
prime mover."
Subsequently in the Criscom and Wagner patent (3) in claim 5 the
statement is
"5. In a transmission system, a synchronous generator, a
transmission line connected thereto, said line having a
fault-responsive sectionalizing means, a prime-mover for supplying
mechanical power to said generator, and electric fault-responsive
means for temporarily altering the available generator-turning
power delivered to said generator within a time which is small in
comparison to the half-period of oscillation of the system, the
direction of alteration being such as to reduce said
oscillation."
In the case of the Staege patent the disclosure calls for restoring
driving power to its predisturbance value after a "predetermined
time."
In the case of the Griscom and Wagner patent both the disclosure
and all claims that relate to driving power reduction refer to
"temporarily" altering or reducing it or words to that general
effect.
In 1929 and 30, at the writer's suggestion, the GE Co. carried out
tests on a 50,000 kw reheat type turbine generator which
demonstrated the feasibility of employing very rapid momentary
reduction of turbine driving power as a way to improve power system
stability (2).
When the writer first filed the patent application that led in due
course to U.S. Pat. No. 3,051,842, he at first gave consideration
only to new ways to make use of application of an artificial or
braking load and fast momentary reduction of turbine driving power
(cf claims 1 through 15), but before the patent issued he modified
it to also include essentially what is covered in claim 2 of
Griscomb and Wagner with the added provision that
". . . the fault is caused to effect a modification of generator
prime mover driving power characteristics whereby it results that
following clearance of the fault and return to steady power flow
conditions the amount of power transmitted over the transmission
system from the generating segment to the receiving segment is
reduced relative to conditions obtaining just prior to the fault."
(cf column 3 lines 1 through 8).
What the writer had added was the very important concept of
effecting a driving power reduction that was not merely rapid
enough to favorably effect power system stability during the first
forward swing of the generator rotor following a line fault, which
is to say within the first half-period of oscillation of the
system, as in Griscom and Wagner, but that also operated to hold
driving power in the post fault period below its prefault
value.
What Staege, and Griscom and Wagner, proposed was basically new,
and what the writer added was a basically new improvement over what
they disclosed and claimed.
However when the writer was in process of writing the claims of
U.S. Pat. No. 3,051,842 he had not seen either the Staege, or
Griscom and Wagner patents, and did not find himself equal to the
task of writing the kind of brief strong claims that those patents
incorporated, and above all he was unable to argue successfully
with the then examiner that it would not, in the light of the prior
art of turbine control, be obvious to anyone skilled in the
combined arts of power transmission and turbine control to provide
to restrict the extent of preprogrammed return of driving power to
prefault value during the post fault period.
However as experience well demonstrated, it was not, in fact,
obvious, nor, as brought out in the petition to allow a reissue of
the writer's second patent, was it obvious that, as proposed in
that patent, there are special advantages in combined employment of
fast .[.value.]. .Iadd.valve .Iaddend.action of the sustained
reduction of driving power type, and mometary application of a
braking load.
What has been at stake is that the writer proposed two entirely new
techniques of improving power system stability, which can be
briefly characterized as
a. sustained reduction of driving power type fast valving, or more
simply "sustained type fast valving" and
b. the combination of sustained type fast valving and braking,
which, from the start offered an important potential to allow
either improving reliability of bulk power transmission, or
minimizing need to construct power transmission lines.
However it turned out to be very difficult to evoke interest in
these concepts because of what the writer has termed "the power
technology education gap," which relates to the fact that, almost
without fail, mechanical engineers do not understand what
determines power system stability, and electrical engineers usually
know relatively little about steam turbines and steam
generators.
Knowledge in these areas has tended to be closely compartmented,
this being somewhat more true in the U.S. than on the continent of
Europe, where turbine producers have tended to produce boilers as
well.
As the writer began to work toward the implementation of his
concept of use of very rapidly effected sustained type reduction of
turbine driving power as a means of improvement of system
stability, he encountered the situation that, whereas power
transmission system planners could be easily convinced of the merit
of what he proposed as a way to improve stability and minimize need
to build lines, turbine and boiler people raised objections which,
in time sequence, were to the effects that what was proposed
would
A. cause lifting of and damage to safety valves,
B. cause objectionable thermal fatigue effects,
C. require changes to turbine control systems,
D. cause objectionable steam generator transients,
E. cause
1. greater control complexity,
2. additional duty on intercept valves,
3. more severe duty on intercept valves,
4. burden of drain system instability,
5. certain blowing of MSR pressure relief valves,
item E above representing the recently stated position of the GE
Co's turbine people as regards fast valving generally, whether of
the momentary or sustained reduction of driving power type.
Because of these objections it became necessary to find
remedies.
Also, as time went on, refinements were added, such as provision to
at first employ momentary fast valving, but, in certain situations,
within a fraction of a second, convert to sustained type (46) or
vice versa (68), and also to alter the extent of preprogrammed
sustained driving power reduction with a fraction of a second of
initiation of fast valving.
The present application deals with a particular set of ways of
avoiding adverse effects on safety valves, turbine valves, and
steam generators when fast valving of the sustained reduction of
driving power type is made use of as a way to preserve system
stability when threatened by events such as, but not limited to,
line faults, when the event could operate to cause instability.
Therefore it depends on use of the basically new concept of
responding to suddenly occurring events that could adversely affect
power system stability by doing things that initiate a sustained
type reduction of turbine driving power that is adapted to take
place fast enough to serve the purpose of helping to prevent
development of system instability.
When it comes to the hardware, naturally each turbine producer
prefers to utilize the hardware that he already has developed and
is supplying.
In the U.S., GE and Westinghouse use valve actuator oil dump valves
to effect very rapid valve closure, and these dump valves have to
be closed before reopening can begin.
GE's dump valves reclose much more slowly than those of
Westinghouse, but this is merely objectionable and not necessarily
fatal to success especially when braking is utilized.
Continental European turbines, or at least those of the Brown
Boveri Co., use large servo valves as a way to cause fast valve
closure.
Westinghouse large nuclear turbines are especially in need of
provision to rapidly reopen their butterfly type valves and, at the
instance of the TVA, Westinghouse is currently in process of
providing for fast opening.
To attain desirable speeds of opening, oil pumps such as are
normally employed to supply oil for valve reopening purposes, have
to be supplemented by oil accumulators.
Also, in order to add the useful feature of fast partial reopening
of intercept valves, if large enough servo valves are not
available, they must be provided, or otherwise cam operated
decelerating valves or metering cylinders as described in this
application can be used.
Also where intercept valves require to be held in a partly open
position on a sustained basis, ability to so operate without valve
damage is required.
The details of how these things can be done, and are being done in
the case of TVA steam-electric installations, are unimportant
because there are many ways to proceed and each turbine control
system designer and each valve designer is free to use whatever
approach in his opinion suits best in his case.
In the course of conversations with the key turbine control and
valve designers of GE, Westinghouse, and Brown Boveri, except when
it came to provision for fast opening of large valves of nuclear
turbines against full MSR pressure, there has never been any
question as to the feasibility of providing features that the
writer has called for if only
a. there is a genuine economic advantage in their use,
b. adverse effects contingent on their use can be avoided.
With this in mind, and to render the claims easy to read, it has
appeared advantageous to employ a claim wording that does not go
into detail when it comes to what in the prior art is available and
would be made use of.
Griscom and Wagner patent claim number 5 used the terms
". . . means for temporarily altering the available
generator-turning power delivered to said generator within a time
which is small in comparison to the half-period of oscillation of
the system . . . "
In the context of the present application this wording could be
paraphrased to read as below
--means for effecting a sustained reduction of the driving power of
the turbine within a time period which is small in comparison with
the half period of oscillation of the system--
However this phraseology would be too narrow
a. first because ordinarily it would be desirable for driving power
to sustain at approximately the value that would be arrived at at
the end of the half period of oscillation and
b. second because as brought out in references 23, 46, and 68 there
are exceptions to the rule.
Thus what needs to be done varies from situation to situation,
while also as brought out in references 23, 31, and 32, it can be
advantageous to boost rather than reduce driving power.
In general there are several situations in which it is useful to
reposition turbine valves as rapidly as possible, and it follows
that there can be an advantage in providing a common way to
characterize this type of valve action.
To have a simple terminology the words fast turbine valving have
seemed best to fit the bill (64).
Historically the first, and still the most important, purpose of
fast valving has been to minimize development of overspeed, on full
or partial loss of load, by rapidly closing valves.
Also there has always been, and remains, a need to prevent too
great a drop in speed when load suddenly increases, by providing to
rapidly open valves.
However, as a new development, fast turbine valving can also be
used as a way to avoid development of system instability as a
consequence of stability endangering events, and when so used can
be employed in two ways, as below,
a. to reduce turbine driving power by closing valves, in the case
of development of stability endangering events of a type adapted to
cause a generator to experience a sudden at least momentary
reduction of load,
b. to increase turbine driving power by opening valves in the case
of events of a type adapted to cause a generator to experience a
sudden increase in load
while those skilled in the art of turbine control know how this can
be done, by providing within the turbine's control system for a
predetermined response to a fast valving signal input which
response will comprise a preprogrammed process of valve
repositioning.
Now, in the above, it is to be understood that a turbine's control
system can incorporate more than one preprogrammed process of fast
valving in response to a fast valving signal, as is well brought
out in reference 54, which comprises GE U.S. Pat. No. 3,601,617,
and in which provision is made to effect fast valving, both
a. for overspeed protection, and
b. for improvement in system stability,
with valve behavior dependent on which of two types of fast valving
signals has been generated, program (a) being made responsive to a
fast valving signal generated as a result of a sudden full or
partial loss of station load not involving a line fault, and
program (b) being made responsive to the occurrence of a fault.
Also, as brought out in the writer's various patents and
publications that deal with fast valving for stability improvement,
the nature of the preprogrammmed valving cycle can be automatically
varied in dependence on such factors as prefault transmitted load
(21), the occurrence or non-occurrence of a refault after reclosure
of faulted line circuit breakers (22, 23), the trip-off of
generators, and the opening of intersystem ties (31, 32), the
development of delay in fault clearance (46, 68), and the type and
location of line faults (44, 64), and that in these connections it
can be desirable to provide, as described in reference 64 and 68,
so that when a fast valving signal is generated in response to a
system stability endangering event the signal is made available,
selectively, as an input to one of a group of two or more turbine
control system fast valving signal input channels, each of which,
when a signal is received, activates a different portion of the
turbine's control system, and brings into effect a different type
of preprogrammed fast valving cycle.
Whereas not made explicit in the claims it is to be understood that
normally, as shown in the figures, the power delivered by
alternating current generators is stepped up in voltage by
generator transformers, and delivered via circuit breakers,
supplied to transmission systems which serve to interconnect the
generator with other generators, while also the point will apply
that large steam turbines of compound type invariably receive their
steam from steam generators.
Where, as in some cases, direct current lines or ac-dc-ac back to
back converters are made use of, advantage in fast valving for
stability improvement can fail to apply, but this will not be the
case where the turbine generator that would be fast valved is
united to other generators by a plurality of alternating current
transmission circuits.
Where in the above, and in the claims, use is made of the word
preprogrammed, what is to be understood is that where valve
repositioning is involved, on energization of some sort of trigger
device, spring loaded valves will close in a manner that will be
entirely determined by the design of the valves, springs, and valve
actuator oil discharge means.
Also, it will be provided in advance that the reopening process
will begin at a preset point in time following the end of the
closing process.
Further there will be advance provision that will determine the
nature of the stroke of the valve versus time, during the opening
process.
It will also be understood that a preprogrammed process of signal
generation and control system fast valving input signal channel
selection implies advance determination of what will take
place.
The word sustained is used in the claims in the context of a
preprogrammed process of sustained type partial intercept valve
reopening and is to be understood to mean that the valve ends up in
a partially open position, and will remain there unless and until
something that was not preprogrammed takes place.
In this section on claim terminology, words and phrases that have
been underlined represent, in a sense, a special language that has
proved to be useful when dealing with fast turbine valving for
stability improvement, an area of expertise for which, until
recently, there was no need of specialized language
development.
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