U.S. patent number 3,693,347 [Application Number 05/142,471] was granted by the patent office on 1972-09-26 for steam injection in gas turbines having fixed geometry components.
This patent grant is currently assigned to General Electric Company. Invention is credited to William H. Day, Paul H. Kydd.
United States Patent |
3,693,347 |
Kydd , et al. |
September 26, 1972 |
STEAM INJECTION IN GAS TURBINES HAVING FIXED GEOMETRY
COMPONENTS
Abstract
Control means are provided for utilizing maximum tolerable
amounts of steam in gas turbines having fixed geometry components
under various operating conditions. Optional means include: means
for automatically holding a constant cycle pressure ratio under all
ambient conditions; temperature sensing control means for
automatically adjusting steam injection in both low and high
temperature ambients to avoid visible plumes and to avoid acid
condensation, respectively; or combined temperature and humidity
sensing control means for automatically optimizing steam injection
under all conditions of ambient temperature and humidity.
Inventors: |
Kydd; Paul H. (Scotia, NY),
Day; William H. (Scotia, NY) |
Assignee: |
General Electric Company
(N/A)
|
Family
ID: |
22499959 |
Appl.
No.: |
05/142,471 |
Filed: |
May 12, 1971 |
Current U.S.
Class: |
60/775; 60/39.3;
60/39.55 |
Current CPC
Class: |
F01K
21/047 (20130101); Y02E 20/14 (20130101) |
Current International
Class: |
F01K
21/04 (20060101); F01K 21/00 (20060101); F02g
003/00 () |
Field of
Search: |
;60/39.55,39.3,39.53,39.05,39.54,39.26 |
References Cited
[Referenced By]
U.S. Patent Documents
Foreign Patent Documents
Primary Examiner: Croyle; Carlton R.
Assistant Examiner: Olsen; Warren
Claims
What we claim as new and desire to secure by Letters Patent of the
United States is:
1. In a gas turbine power plant wherein the turbine is mechanically
connected to and drives a compressor; said compressor supplies
compressed air to a combustor in flow communication therewith;
steam injecting means including steam generating means is in flow
communication with said combustor and generates and supplies steam
thereto; means in flow communication with said combustor supplies
fuel thereto for combustion thereof with air in said combustor for
the generation of hot gases, and said combustor supplies the hot
gases generated therein to said turbine being in flow communication
therewith, the combination with said steam generating means of
means to automatically control the generation of steam for
admission to said combustor, said control means comprising:
a. means in flow communication with said compressor for generating
a control signal and
b. means connected to said control signal generating means and
responsive to said control signal for adjusting the rate of heat
energy input to said steam generating means.
2. The combination of claim 1 wherein said steam generating means
is in flow communication with the exhaust system of said turbine
and said adjusting means determines the flow of exhaust gas
thereto.
3. The combination of claim 1 wherein said steam generating means
comprises a first steam generator in flow communication with the
exhaust system of said turbine and a second steam generator in
series with said first steam generator, said first steam generator
alone having the exhaust gas input thereto adjustable by said
adjusting means.
4. The combination of claim 1 wherein the means for generating a
control signal comprises:
a. electrical signal comparing means having first and second inputs
and having an output, said output being electrically connected to
said adjusting means,
b. means electrically connected to said first input of said
comparing means and in flow communication with the compressor
discharge for sensing the compressor discharge pressure and
generating a pressure-response signal quantitatively related
thereto and
c. means electrically connected to said second input of said
comparing means for applying a bias signal thereto, said comparing
means supplying a control signal to said adjusting means via said
output when the relationship between said bias signal and said
pressure-response signal deviates from some predetermined
value.
5. The combination of claim 4 wherein said means for applying a
bias signal is a fixed voltage source.
6. The combination of claim 4 wherein said means for applying a
bias signal includes a voltage generator and a temperature sensor
having an electrical signal output quantitatively related to the
temperature sensed, said temperature sensor being located adjacent
the inlet to said compressor and being electrically connected to
said voltage generator, said voltage generator being electrically
connected to said second input and the bias signal generated
thereby being quantitatively related to the signal from said
temperature sensor.
7. The combination of claim 4 wherein the means for applying a bias
signal includes a temperature sensor having an electrical signal
output quantitatively related to the temperature sensed; first and
second voltage generators electrically connected at their
respective inputs to said temperature sensor; a humidity sensor
having an electrical signal output quantitatively related to the
relative humidity sensed; a voltage multiplier having separate
inputs electrically connected to the outputs of said second voltage
generator and said humidity sensor, respectively; and the outputs
of said first voltage generator and said voltage multiplier being
electrically connected to a summing junction, the bias signal
output of said summing junction being electrically connected to
said comparing means and said temperature sensor and said humidity
sensor being located adjacent the inlet to said compressor.
8. The combination of claim 4 wherein the means for sensing and
generating a pressure-response signal is a pressure transducer.
9. The combination of claim 1 wherein said adjusting means is a
flow bypass having powered actuating means, said flow bypass being
in flow communication with said steam generating means.
10. The combination of claim 2 wherein said adjusting means is a
flow bypass having powered actuating means, said flow bypass being
in flow communication with the outlet of said turbine, with said
steam generating means and with mixing means located downstream in
the turbine exhaust system.
11. In a gas turbine power plant wherein the turbine is
mechanically connected to and drives a compressor; said compressor
supplies compressed air to a combustor in flow communication
therewith; steam injecting means including steam generating means
is in flow communication with said combustor and generates and
supplies steam thereto; means in flow communication with said
combustor supplies fuel thereto for combustion thereof with air in
said combustor for the generation of hot gases, and said combustor
supplies the hot gases generated therein to said turbine being in
flow communication therewith, the combination with said steam
generating means of means to automatically control steam flow to
said combustor, said control means comprising:
a. means in flow communication with said compressor for generating
a control signal and
b. means for adjusting the admission of steam to said combustor,
said adjusting means being in flow communication with both said
steam injecting means and said combustor and being automatically
responsive to said control signal.
12. The combination of claim 11 wherein said steam generating means
is in flow communication with the exhaust system of said
turbine.
13. The combination of claim 11 wherein the means for generating a
control signal comprises:
a. electrical signal comparing means having first and second inputs
and having an output, said output being electrically connected to
said adjusting means,
b. means electrically connected to said first input of said
comparing means and in flow communication with the compressor
discharge for sensing the compressor discharge pressure and
generating a pressure-response signal quantitatively related
thereto and
c. means electrically connected to said second input of said
comparing means for applying a bias signal thereto, said comparing
means supplying a control signal to said adjusting means via said
output when the relationship between said bias signal and said
pressure-response signal deviates from some pre-determined
value.
14. The combination of claim 13 wherein said means for applying a
bias signal is a fixed voltage source.
15. The combination of claim 13 wherein said means for applying a
control bias signal includes a voltage generator and a temperature
sensor having an electrical signal output quantitatively related to
the temperature sensed, said temperature sensor being located
adjacent the inlet to said compressor and being electrically
connected to said voltage generator, said voltage generator being
electrically connected to said second input and the bias signal
generated thereby being quantitatively related to the signal from
said temperature sensor.
16. The combination of claim 13 wherein the means for applying a
bias signal includes a temperature sensor having an electrical
signal output quantitatively related to the temperature sensed;
first and second voltage generators electrically connected at their
respective inputs to said temperature sensor; a humidity sensor
having an electrical signal output quantitatively related to the
relative humidity sensed, a voltage multiplier having separate
inputs electrically connected to the outputs of said second voltage
generator and said humidity sensor, respectively; and the outputs
of said first voltage generator and said voltage multiplier being
electrically connected to a summing junction, the output of said
summing junction being electrically connected to said comparing
means and said temperature sensor and said humidity sensor being
located adjacent the inlet to said compressor.
17. The combination of claim 13 wherein the means for sensing and
generating a pressure-response signal is a pressure transducer.
18. The combination of claim 11 wherein said adjusting means is a
flow by-pass having powered actuating means.
19. In a gas turbine power plant wherein a liquid-cooled turbine is
mechanically connected to and drives a compressor; said compressor
supplies compressed air to a combustor in flow communication
therewith; steam injecting means including steam generating means
is in flow communication with said combustor and supplies steam
thereto; means in flow communication with said combustor supplies
fuel thereto for combustion thereof with air in said combustor for
the generation of hot gases and said combustor supplies the hot
gases generated therein to said turbine being in flow communication
therewith, the combination with said steam injecting means of:
a. first steam generating means in flow communication with the
exhaust system of said turbine,
b. second steam generating means in series with said first steam
generating means; said second steam generating means being in heat
exchange relationship with the cooling circuit of said turbine,
c. means in flow communication with said compressor for generating
a control signal and
d. means connected to said control signal generating means and
responsive to said control signal for adjusting the flow of exhaust
gas to said first steam generating means.
20. The combination of claim 19 wherein the means for generating a
control signal comprises:
a. electrical signal comparing means having first and second inputs
and having an output, said output being electrically connected to
said adjusting means,
b. means electrically connected to said first input of said
comparing means and in flow communication with the compressor
discharge for sensing the compressor discharge pressure and
generating a pressure-response signal quantitatively related
thereto and
c. means electrically connected to said second input of said
comparing means for applying a bias signal thereto, said comparing
means supplying a control signal to said adjusting means via said
output when the relationship between said bias signal and said
pressure-response signal deviates from some predetermined
value.
21. The combination of claim 20 wherein said means for applying a
bias signal is a fixed voltage source.
22. The combination of claim 20 wherein said means for applying a
bias signal includes a voltage generator and a temperature sensor
having an electrical signal output quantitatively related to the
temperature sensed, said temperature sensor being located adjacent
the inlet to said compressor and being electrically connected to
said voltage generator, said voltage generator being electrically
connected to said second input and the bias signal generated
thereby being quantitatively related to the signal from said
temperature sensor.
23. The combination of claim 20 wherein the means for applying a
bias signal includes a temperature sensor having an electrical
signal output quantitatively related to the temperature sensed;
first and second voltage generators electrically connected at their
respective inputs to said temperature sensor; a humidity sensor
having an electrical signal output quantitatively related to the
relative humidity sensed; a voltage multiplier having separate
inputs electrically connected to the outputs of said second voltage
generator and said humidity sensor, respectively; and the outputs
of said first voltage generator and said voltage multiplier being
electrically connected to a summing junction, the bias signal
output of said summing junction being electrically connected to
said comparing means and said temperature sensor and said humidity
sensor being located adjacent the inlet to said compressor.
24. The combination of claim 20 wherein the means for sensing and
generating a pressure-response signal is a pressure transducer.
25. The combination of claim 19 wherein said adjusting means is a
flow bypass having powered actuating means, said flow bypass being
in flow communication with said steam generating means.
26. The combination of claim 19 wherein said adjusting means is a
flow bypass having powered actuating means, said flow bypass being
in flow communication with the outlet of said turbine, with said
steam generating means and with mixing means located downstream in
the turbine exhaust system.
27. In the operation of a gas turbine power plant in the steam
injection mode wherein the following steps are performed:
generating steam from liquid water; compressing atmospheric air to
superatmospheric pressure; passing the compressed air to a
combustion zone, where fuel is introduced and continuous combustion
occurs; passing the generated steam to said combustion zone, and
passing hot gases continuously from said combustion zone through an
expansion zone where mechanical energy is abstracted in
substantially greater amount than the mechanical energy absorbed in
the compression step, the combination with said series of step
of:
a. automatically controlling the flow of steam to said combustion
zone by means of a control signal, said control signal resulting
from the interrelation of a bias signal and a signal quantitatively
comparable to the compressor pressure ratio.
28. The steps of operation of a gas turbine power plant as recited
in claim 27 wherein the bias signal is a constant voltage
signal.
29. The steps of operation of a gas turbine power plant as recited
in claim 27 wherein the bias signal is quantitatively related to
the ambient temperature.
30. The steps of operation of a gas turbine power plant as recited
in claim 27 wherein the bias signal is quantitatively related both
to the ambient temperature and to the ambient humidity.
Description
BACKGROUND OF THE INVENTION
The injection of steam into the combustion chamber of a gas turbine
is broadly old as is shown in U.S. Pat. No. 2,678,531--Miller and
U.S. Pat. No. 3,353,360--Gorzegno. The operation of gas turbines in
the steam injection mode provides greater output, because of the
increased mass flow through the turbine and because of the higher
specific heat of the turbine working fluid. A higher cycle
efficiency also results, because this mass flow is obtained without
the expenditure of additional compressor power, and the steam for
the steam injection can be generated utilizing heat losses or
exhaust heat which otherwise is not effectively utilized.
SUMMARY OF THE INVENTION
Control means are provided for utilizing the maximum amounts of
steam that can be tolerated in the operation of gas turbines having
fixed geometry components under various operating conditions.
Optional means are provided as follows: means for automatically
holding a constant cycle pressure ratio (compressor discharge
pressure/ambient pressure) under all ambient conditions;
temperature sensing control means for automatically adjusting steam
injection in both low and high temperature ambients to avoid
visible plumes and to avoid acid condensation, respectively; or
combined temperature and humidity sensing control means for
automatically optimizing steam injection under all conditions of
ambient temperature and humidity.
BRIEF DESCRIPTION OF THE DRAWING
The exact nature of this invention as well as objects and
advantages thereof will be readily apparent from consideration of
the following specification relating to the annexed drawing in
which:
FIG. 1 is a schematic representation of one embodiment of means
according to this invention for automatically controlling the
extent of steam injection employed in a fixed geometry continuous
flow gas turbine;
FIG. 2 shows a second embodiment of the control voltage generator
shown in FIG. 1 including ambient temperature as a control
parameter;
FIG. 3 is another modification of the control voltage generator
shown in FIG. 1 including both ambient temperature and ambient
humidity as control parameters;
FIGS. 4 and 5 considered together constitute a gas turbine
performance map setting forth output and thermal efficiency as a
function of ambient temperature at a series of turbine inlet
temperatures;
FIG. 6 is a schematic representation of an automatically controlled
steam injection system according to this invention wherein in
addition to the steam injection means of FIG. 1 steam is also
generated from the heat in the coolant stream of a liquid cooled
turbine and from the liner of the combustor and
FIG. 7 is a schematic representation of a system in which steam is
generated at a substantially fixed rate and a control voltage
generator according to this invention is used to adjust the
admission of steam to the combustor.
DESCRIPTION OF THE PREFERRED EMBODIMENT
Although steam injection, per se, of gas turbines has been
previously employed, no consideration appears to have been given to
the elimination of problems encountered in the use of steam
injection. These problems include the emission of visible exhaust
plumes at low ambient temperatures and the occurrence of sulfuric
acid condensation in the system under high ambient/low stack
temperature conditions. The emission of visible plumes and/or
exhausts containing droplets of acid are unacceptable in view of
the increasing concern for the quality of the environment. Further,
the corrosion caused in the gas turbine exhaust system by sulfuric
acid generation must be avoided. Control over the steam injection
rate insuring an ecologically acceptable stack exhaust is highly
desirable for environmental pollution considerations, of course,
however, it has also been found that this control capability can
still further improve the operation of gas turbines using steam
injection.
Investigations during the development of the instant invention have
shown that steam injection reduces the emission of nitric oxide by
diluting the combustion air and by reducing the maximum flame
temperature. Reduction of flame temperature is important, because
the bulk of the nitric oxide is produced at temperatures in excess
of about 3,400.degree.F.
In the steam injection process high-pressure steam can be used to
atomize heavy fuel oil and eliminate the cost and the power
consumption of the atomizing air booster compressor. Atomization
energy for improved combustion is virtually unlimited with the use
of heat recovery steam as the atomizing medium. Additional
advantages also accrue in that by using high-pressure steam as the
atomizing medium the problem of formation of deposits in the
turbine and in the heat recovery boiler is reduced. Further, by
concentrating the steam flow in the primary zone of the combustor
the nitric oxide emission can be even more effectively reduced.
It has also been shown during the aforementioned investigations
that even though visible plume-free operation of gas turbines
should be possible at ambient temperatures above about 75.degree.F
when using very substantial steam flows, the problem of the
condensation of sulfuric acid in the stack (whereupon this
objectionable corrosive condensate is present in the stack exhaust)
still remains. Further, the generation of visible plumes at ambient
temperatures below 75.degree.F is still a problem. Both of these
troublesome conditions can be eliminated by the practice of at
least one of the several options presented in the instant
invention.
FIG. 1 schematically represents a gas turbine 10 having fixed
geometry components; compressor 11, combustor 12 and turbine 13.
Gas turbine 10 has been provided with steam injection means and
controls therefor in accordance with the instant invention.
The steam injection means comprises a steam separator 14 [which may
for example be of the drum variety], conduit 16 carrying a hot
water/steam mixture to steam separator 14, conduit 17, which
conducts steam from steam separator 14 to the combustor 12, conduit
18 which removes liquid water to the feedwater pump 19, conduit 20
which conducts water to boiler 21, inlet water conduit 22 for water
makeup and valved blow-down line 23. A flash tank and pressure
reducing valve combination as is shown in the aforementioned
Gorzegno patent (incorporated by reference) may be substituted for
steam separator 14.
During operation in the steam injection mode compressor 11 takes in
atmospheric air and forces it under substantial superatmospheric
pressure into combustor 12. Fuel is supplied to combustor 12
through fuel inlet 24 and steam is injected into combustor 12 via
line 17. Either high-pressure air or the steam (or suitable
mixtures thereof) may be employed to atomize the fuel in combustor
12. Combustion of the fuel in combustor 12 produces hot gases,
which pass through turbine 13, where expansion of the hot gases
occurs with the generation of mechanical energy part of which
drives compressor 12 via shaft 26 and part of which is available to
drive a load via shaft 27.
Control voltage generator 31 consists of the preset voltage source
32, pressure transducer 33 and comparator circuit 34. These
components are electrically connected as shown. When operating,
voltage source 32 continuously applies a fixed biasing voltage
E.sub.O to comparator circuit 34 and pressure transducer 33
continuously applies voltage E.sub.P to comparator circuit 34,
E.sub.P being a voltage that is proportional to the compressor
discharge pressure applied to pressure transducer 33 via conduit
36. Comparator circuit 34 is adjusted so that for a voltage E.sub.P
reflecting a compressor discharge pressure equal to the selected
operating value of cycle pressure ratio selected as described
hereinabove, the bias voltage E.sub.O is just compensated.
In the event of a change in the compressor discharge pressure,
voltage E.sub.P will not be equal to bias voltage E.sub.O and the
voltage error is the control voltage (E.sub.E) that is thereby
generated (and amplified, if required) is supplied to by-pass unit
37 (with motorized actuator 37a), e.g., a damper actuator (as
manufactured by the General Electric Company, Instrument
Department, Lynn, Mass.), so as to change the position of baffle
37b and thereby modify the amount of exhaust gas passing through
boiler 21 to reduce and then eliminate the error. Thus, if voltage
E.sub.P is temporarily greater than bias voltage E.sub.O, a
negative control voltage E.sub.E is generated resetting bypass
actuator 37a to decrease the amount of exhaust gas from turbine 13
passing through line 38, bypass unit 37, line 38a and boiler 21.
This change results in a decrease in the amount of steam generated
in boiler 21 and separated in steam separator 14 thereby decreasing
the steam input to combustor 12. If the reverse situation occurs
(E.sub.P is less than E.sub.O), a positive control voltage E.sub.E
results and bypass actuator 37a is readjusted so as to increase the
exhaust flow through boiler 21 and decrease the amount of exhaust
passing through the exhaust conduit 39 and mixer 40 to the stack.
The changes in steam flow so accomplished will reduce and eliminate
control voltage E.sub.E changing the pressure ratio across
compressor 12 by changing the amount of mass flow occurring at
fixed temperature through the fixed geometry turbine. If desired,
some of the injected steam is introduced into the head end of the
combustor and the balance of the input is introduced therein
downstream of the head.
Valve 25 in steam line 17 is controlled in the conventional manner
(as by sensing the rotational speed of shaft 27) to compensate for
large increases or decreases in gas turbine load. Valve 25 may be a
throttling/shut-off type valve or a bypass valve.
There are at least two types of situations in which the automatic
elimination of visible exhaust plume and exhaust system corrosion
must be accomplished at some turbine inlet temperature lower than
the temperature at which steam injection which maintains constant
pressure ratio will do so automatically. In such situations the
control voltage generator device 31 will not provide sufficiently
sophisticated control. Either of the control voltage generators
shown in FIGS. 2 and 3 may then be employed to effect control such
that the maximum amount of steam is generated (and injected) as
required for maximum output and thermal efficiency over the
preselected range of ambient temperatures. Examples of the
aforementioned types of situations are as follows:
a. when it is desired to operate the machine at a turbine inlet
temperature below the maximum turbine inlet temperature thereof
(although such operation is within its capability) in order to
achieve reduced power output but yet operate in this regime at
maximum steam flow and efficiency and
b. when the compressor/turbine combination is such that the turbine
cannot tolerate as high an inlet temperature as is necessary for
the maintenance by steam injection of the maximum pressure ratio
over the full preselected range of ambient temperatures.
The device of FIG. 2 supplies a voltage to automatically control
steam generation as a function of ambient temperature while the
device shown in FIG. 3 supplies a voltage to automatically control
steam generation as a function of both the ambient temperature and
ambient relative humidity (RH). All components shown in connection
with all the control means disclosed herein are commercially
available items.
The device 41 shown in FIG. 2 is interchangeable with control
voltage generator 31 shown in FIG. 1. Pressure transducer 42 is
hydraulically connected via line 36 to the compressor discharge.
Voltage E.sub.P having a value proportional to the compressor
discharge pressure is supplied to comparator circuit 43 as
described hereinabove. Temperature sensor 44 (e.g., a thermocouple
or temperature transmitter such as GE/MAC type 550 manufactured by
the General Electric Company, Instrument Department, Lynn, Mass.)
is located at or near the compressor inlet emitting a voltage
E.sub.T reflecting the ambient temperature conditions. Temperature
sensor 44 is electrically connected to function generator 46 (e.g.,
GE/MAC type 566 function generator manufactured by the General
Electric Company, Instrument Department, Lynn, Mass.) as shown so
as to apply voltage E.sub.T thereto. In function generator 46 (set
for a 100 percent relative humidity condition), a bias voltage
E.sub.O is generated as a function of voltage E.sub.T and, as a
result, reflects the effect of any ambient temperature in the
preselected range at 100 percent RH. Voltages E.sub.O and E.sub.P
are applied to comparator circuit 43 in the manner described
hereinabove for comparator circuit 34. The value of the voltage
error (control voltage E.sub.E), if any, determines the setting of
motorized bypass unit 37 in the same manner as described
hereinabove.
Thus, should the ambient temperature decrease below the point at
which a constant pressure ratio can be maintained by steam
injection without visible plume, there will be automatic
compensation of the rate of steam injection, because the electrical
control signal E.sub.E will automatically relate to the selected
compressor discharge pressure compensated for low ambients. Thus,
control voltage E.sub.E (via bypass actuator 37a) will adjust the
rate of steam injection to combustor 12 as required to avoid
visible plumes in the exhaust. Similarly, should the ambient
temperature increase above the point at which a constant pressure
ratio can be maintained by steam injection without forming acid
condensate in the exhaust, control voltage E.sub.E will
automatically properly adjust the rate of steam injection to
combustor 12 to eliminate the acid condition. This mode of
operation will allow satisfactory performance at all ambient
relative humidities, but must sacrifice the opportunity to add more
steam at ambient humidities lower than 100 percent RH.
The control voltage generator 51 includes pressure transducer 52,
the electrical output (voltage E.sub.P) of which passes to
comparator circuit 53 as described hereinabove and the electrical
signal E.sub.P is compared therein to biasing signal E.sub.O, which
latter voltage factors into the automatic control function the
parameters of ambient temperature and ambient humidity. Both a
temperature sensor and a humidity sensor (e.g., of the surface ion
exchange type as manufactured by the Amlab Company of Essex, Conn.,
used in a bridge circuit with thermistor compensation for
temperature effects) are located at or near the compressor inlet
and these sensors respectively emit electrical signals E.sub.T and
E.sub.RH. The humidity sensor 54 is adjusted so that at 100 percent
RH the output voltage E.sub.RH is zero and at zero relative
humidity E.sub.RH is one unit. Temperature sensor 55 is
electrically connected to each of function generators 56 and 57.
Function generator 56 emits voltage E.sub.O ' as some function of
E.sub.T (and therefore as a function of the ambient temperature) at
100 percent RH. Function generator 56 is electrically connected to
summing junction 58,which in turn is electrically connected to
comparator circuit 53.
The electrical signal E.sub.T impressed on function generator 57
generates the voltage designated as .DELTA.E.sub.O. This electrical
signal (voltage .DELTA.E.sub.O) reflects any requisite correction
voltage for the actual ambient temperature at a relative humidity
of zero or, in effect is indicative of the rate of steam injection
that should be employed under these conditions. Voltage
.DELTA.E.sub.O is then further modified (as described hereinbelow)
in interpolation circuit 59 (e.g., voltage multiplier, type 564S
manufactured by General Electric Company, Instrument Department,
Lynn, Mass.) to reflect the actual ambient humidity sensed by
humidity sensor 54. Voltage E.sub.RH emitted by humidity sensor 54
reflects the actual ambient humidity and is indicative of the
fraction of voltage .DELTA.E.sub.O that can form part of the bias
voltage to be applied to comparator circuit 53.
As shown, both voltage E.sub.RH and voltage .DELTA.E.sub.O are
introduced to interpolation circuit 59. The interpolation circuit
59 electrically multiplies voltage .DELTA.E.sub.O by voltage
E.sub.RH and the product thereof (voltage .DELTA.E.sub.O ')
reflects the incremental rate of steam injection that can be
tolerated at the ambient temperature and ambient relative humidity
over the rate of steam injection permissible for the ambient
temperature/100 percent RH condition. Interpolation circuit 59 is
electrically connected to summing junction 58 to which the
electrical signals E.sub.O ' (representing rate of steam injection
for the ambient temperature at 100 percent RH) and .DELTA.E.sub.O '
(representing the increment of added rate of steam injection for
ambient humidity) are introduced. In summing junction 58, E.sub.O '
and .DELTA.E.sub.O ' are added to produce the net biasing voltage
E.sub.O impressed upon comparator circuit 53. Any resulting error
signal E.sub.E from comparator circuit 53 controls the setting of
actuator 37a in the same manner described hereinabove thereby
providing automatically optimized operation at all ambient
temperatures (in the preselected range) and all ambient relative
humidities.
Although the control devices illustrated herein are electrical in
nature, this invention is intended to encompass hydraulic,
pneumatic and mechanical analogs of these electrical devices. In
each instance, it is required to produce a signal quantitatively
related to the pressure ratio and interrelate a bias signal
therewith. The bias signal may have a constant value or may be
variable either as a function of ambient temperature or as a
function of both ambient temperature and ambient humidity.
Any one of the three optional control voltage generators described
hereinabove may be utilized for controlling the steam injection
into any given gas turbine. The choice of which one is to be used
will be determined by the characteristics of the gas turbine in
question, the range of ambient temperature and relative humidity
over which the machine must operate and whether the power output
and efficiency are to be optimized with regard to relative
humidity.
The characteristics of the gas turbine which are important are the
compressor map (pressure ratio versus air flow at various speeds),
which defines the stall or pulsation limit as a function of speed,
and the first stage turbine nozzle area. The turbine nozzle area
must be large enough that the compressor does not stall at maximum
turbine inlet temperature and minimum ambient air temperature under
which conditions the air flow and pressure ratio of the compressor
are high due to the high inlet air density. Consequently at higher
ambient temperatures additional mass flow can be accepted by the
turbine without stalling the compressor.
The first step in selecting a control voltage generator from the
options disclosed herein for a given gas turbine is to choose a
turbine inlet temperature and steam flow which provides the desired
balance between power output and efficiency at the design point.
High turbine inlet temperatures provide maximum output (FIG. 4).
Lower turbine inlet temperatures and higher steam flow produce a
higher thermal efficiency (FIG. 5) down to the point at which the
exhaust temperature is too low to generate the required amount of
steam or at which the decline in available energy due to reduced
turbine inlet temperature is no longer offset by the increase in
available energy from the permissible increase in steam addition.
The above-noted combination of turbine inlet temperature and steam
flow will be chosen to increase the pressure ratio to the maximum
that the compressor can deliver with an adequate stall margin.
The next step in selecting the control system is to investigate the
performance of the gas turbine over the intended range of ambient
temperature. The objective is to maintain optimum performance over
as wide a range of ambient conditions as are to be encountered.
This is most easily accomplished by holding turbine inlet
temperature constant via the conventional exhaust temperature
measurement and fuel control system and holding pressure ratio
constant at its maximum value by controlling the rate of steam
injection. It may be that for the given gas turbine components and
turbine inlet temperature constant pressure ratio operation can be
achieved over the entire range of expected ambient temperature. In
this case control voltage generator 31 will suffice.
If at low ambient temperatures and 100 percent RH it is found
either that the exhaust moisture content is such that a visible
plume forms, or that at high ambient temperatures and 100 percent
RH,acid condensation occurs due to excessive steam flow and
correspondingly low stack temperature, it will be necessary to
restrict the steam flow into the combustor at low temperatures, at
high temperatures or both. This restriction of steam flow, which
will reduce the pressure ratio and the performance of the gas
turbine at extreme ambient conditions can be accomplished with
control voltage generator 41.
If it is desired to take advantage of the fact that low ambient
relative humidity will reduce the tendency to generate an exhaust
plume or stack condensation, one can extend the region of maximum
steam flow and performance under low relative humidity conditions
by using control voltage generator 51.
In all cases it is desired to achieve the maximum steam flow
permitted by the boundaries imposed by exhaust plume formation,
compressor stall, and acid condensation, at the chosen turbine
inlet temperature. Higher turbine inlet temperatures widen the
range of ambient temperature over which operation at constant
maximum pressure ratio is possible. The operating boundaries for a
representative gas turbine at different turbine inlet temperatures
are shown in FIGS. 4 and 5. Thus, for operation at each of the
turbine inlet temperatures shown, the compressor stall boundary
lies between letters a and b; the exhaust plume boundary lies to
the low ambient temperature side of letter a and the acid
condensation boundary lies to the high ambient temperature side of
letter b. For operation between letters a and b the pressure ratio
is constant. This map further illustrates the substantial change in
thermal efficiency and output between operation in the steam
injection mode and operation without steam injection.
The generation of the data required to prepare a turbine
performance map such as FIGS. 4 and 5 (considered together)
requires a considerable amount of cut-and-try calculating and is,
therefore, most effectively accomplished by the use of a computer,
e.g., time-sharing. The development of a suitable computer program
would employ steps as follows:
a. tentative selection of a range of turbine inlet temperatures
providing a desired balance between thermal efficiency and power
output for the gas turbine,
b. selection from the compressor map of a range of operating
pressure ratios for the gas turbine along the 100 percent speed
curve; the highest pressure ratio being that pressure ratio which
the compressor can deliver without stalling and the lowest pressure
ratio being the pressure ratio for the non-steam injected condition
at lowest ambient temperature,
c. selection of an operating range of ambient temperatures,
d. calculation of the range of operating turbine inlet temperatures
to be employed using known relationships of gas properties (at
different temperatures and steam content) and turbine efficiency
(as a function of pressure ratio, turbine inlet temperature, steam
content and fuel content),
e. selection of a range for the amount of steam to be injected
(i.e., rates of steam injection) into the gas,
f. calculation of a map of the efficiency of the turbine alone as a
function of the parameters in the three selected ranges (pressure
ratio, turbine inlet temperature and steam injection),
g. selection of some value of turbine inlet temperature from the
calculated temperature range,
h. selection of an ambient temperature and a relative humidity of
either zero or 100 percent,
i. calculation of the compressor efficiency for the selected
ambient conditions to determine the maximum pressure ratio
available from the compressor,
j. calculation of the amount of steam and fuel flow required to
create this maximum pressure ratio at the selected turbine inlet
temperature,
k. determination of the efficiency of the turbine itself from the
turbine performance map for the selected turbine inlet temperature,
maximum pressure ratio and gas properties,
l. calculation of the turbine exhaust temperature (accounting for
the effects of cooling and diluting of the gas flow),
m. calculation of the stack temperature considering any heat
removal from the exhaust gas and, knowing the stack temperature,
determining whether stack corrosion (acid condensation) will occur,
and
n. determination of whether visible plume will be generated under
the selected operating conditions at the selected ambient
temperature and relative humidity by calculating the relative
humidity of successive dilutions of stack effluent with the ambient
air.
If it be determined that either an acid condition or visible plume
would occur, the amount of steam being injected is too great. In
such case, the procedure will have to be repeated using a smaller
steam flow and considering the changes (lower pressure ratio) that
accompany the reduced steam injection.
If neither acid condensation nor visible plume occur, the
aforementioned steps are repeated using a different set of ambient
conditions. When a sufficiently large number of sets of ambient
conditions have been considered (e.g., at temperature increments of
about 20.degree.F) one curve of gas turbine thermal efficiency and
output will be generated for the single selected turbine inlet
temperature as described hereinabove. Thereafter, the procedure is
repeated until a map of gas turbine thermal efficiency and output
referred to hereinabove (FIGS. 4 and 5) has been prepared for
different turbine inlet temperatures (at increments of about
100.degree.F). This map provides the option of selecting at will a
turbine inlet temperature for optimizing the combination of gas
turbine thermal efficiency and gas turbine output (consistent with
machine capabilities). Having determined this map, the method
described hereinabove for the determination of the several options
may be carried out.
If the gas turbine is one that may be operated at less than 100
percent speed a tachometer with a signal output proportional to
speed may be introduced to sense the compressor speed and adjust
the sensing of the pressure ratio (described hereinbelow) to
reflect changes in speed. With known gas turbine construction, the
selected ambient temperature range may be as narrow as about
60.degree.F or as wide as at least 110.degree.F depending upon the
selected turbine inlet temperature. The higher the turbine inlet
temperature, the greater the available ambient temperature range.
By way of example, in a General Electric MS7000 gas turbine at peak
reserve turbine inlet temperature the operating ambient temperature
range available, which is free of visible plume or acid
condensation in the exhaust, is 110.degree.F (from 0.degree. to
110.degree.F) at 14.17 psia inlet.
The unexpected aspect of this invention is that having made the
aforementioned determinations, the rate (e.g., pounds of
steam/hour) of injection of steam remains the only control
parameter that is required to simultaneously achieve:
a. the maximum power and efficiency of which the machine is capable
in the selected operating range of ambient temperature,
b. freedom from visible plume and
c. freedom from the formation of acid condensation.
This invention, thus, provides optional means that enable control
of the steam injection rate. These devices vary in their
capabilities for accommodating the extent of ambient temperature
range, when the pressure ratio is not held constant. In the
simplest arrangement (control signal generator device 31) the
selected pressure ratio must be held constant and the turbine is
operated at the constant selected turbine inlet temperature.
Increased efficiency can be obtained by utilizing superheated steam
with a penalty of a slightly higher rate of production of nitric
oxide. Still further increases in specific output and efficiency
can be achieved by increasing the turbine inlet temperature. This
is made possible by utilizing internal cooling. Arrangements for
liquid cooling are described in U.S. Pat. Nos. 3,446,481--Kydd and
3,446,482--Kydd. Internal cooling, of course, results in heat
losses from the gas stream. However, by using this lost heat to
generate steam for injection into the gas turbine in addition to
that generated from the turbine exhaust, approximately 70 percent
of the performance decrease due to the heat losses can be
recovered.
The liquid-cooled turbine parts actually function as a boiler in
the cooling sequence. The liquid coolant may either be circulated
in a fully closed circuit or, in the case of water as the coolant,
in an open circuit from which the steam that is generated may be
withdrawn and replaced with make-up water. The former arrangement
has the advantage of minimizing contaminant content. Such is the
arrangement shown in FIG. 6.
Gas turbine 60 comprises compressor 61, combustor 62 and
liquid-cooled turbine 63. In addition to the steam injection means
and control means therefor shown in FIGS. 1-3 the liquid coolant
for turbine 63 and liquid coolant for combustor 62 are used as
sources of steam generation. The rate of steam generation from
these added sources is fixed by the amount of cooling required and
is substantially constant. Although the rate of steam generation
(and steam injection) is not subject to the control means for the
exhaust-generated steam, this does not pose a problem, because the
turbine inlet temperature for a liquid-cooled turbine may be set
sufficiently high to adequately accommodate the maximum rate of
steam generation from the liquid coolant for turbine 63 and from
the cooling of the liner of combustor 62 without visible plume or
acid condensate formation.
As in the arrangement shown in FIG. 1, the flow bypass 64 receives
exhaust gas from turbine 63 via line 66. Motorized actuator 64a
receives control voltage E.sub.E from control voltage generator 67
electrically connected thereto and fixes the position of damper 64b
in response to voltage E.sub.E. The position of damper 64b
determines what proportion of the exhaust gas passes through bypass
unit 64 to boiler 68 via line 66a and what proportion of the
exhaust gas passes through bypass unit 64 to mixer 69 via line 71.
Control voltage generator 67 may be any of the options 31, 41 or 51
described hereinabove.
Thus, water circulated by pump 72 through line 73 passes through
combustor liner 74, heat exchanger 76 and boiler 68. Steam
generation may occur in heat exchanger 76 and liner 74 and will
always occur in boiler 68 depending on the setting of damper 64b.
The steam/water mixture proceeds to steam separator 77 wherein
liquid and steam are separated, the liquid passing via line 78 to
feed pump 72. Valved blow-down line 79 connected to conduit 78 is
used to remove contaminating material.
Steam from steam separator 77 passes to combustor 62 via line 81.
Valve 82 in steam line 81 is controlled in the conventional manner
to compensate for large increases or decreases in gas turbine load.
Fuel is supplied to combustor 62 via pipe 83 and compressed air
flows to combustor 62 from compressor 61 to burn the fuel and
generate hot gases, which pass to liquid-cooled turbine 63.
In alternate construction (not shown) instead of employing a fully
closed circuit for the turbine liquid coolant and passing the water
flow in line 73 through heat exchanger 74, the turbine cooling
circuit would be made part of the steam injection circuit.
If desired, the exhaust of the turbine may be used in part or in
whole to generate steam at a substantially constant rate in which
case the adjusting means would be disposed between the steam
generating means and the combustor with which it is in flow
communication. The control voltage generator options of this
invention would then be used to control the admission of steam to
the combustor, the steam not injected into combustor 62 being
diverted to other uses, such as process steam or space heating.
Such an arrangement is shown in FIG. 7 in which elements the same
as those in FIG. 1 have like numerals. Flow splitter 91 with an
adjustable baffle is connected between exhaust lines 38 and 38a.
The baffle is positioned so that the amount of exhaust gas passing
through boiler 21 is sufficient to generate steam at the maximum
useable rate. Control voltage generator 92 would be a modified
version of options 31, 41, 51 described hereinabove and controls
the admission of steam to combustor 12 by adjusting the setting of
bypass unit 93 in which baffle 93b is positioned by motor actuator
93a. Unused steam is conducted to an alternate use via pipe 94. If
too much steam is being generated for the combined demands of steam
injection and the alternate use, the baffle in flow splitter 91 is
reset.
The proper setting of flow splitter 91 will, therefore, depend on
the requirements for injection steam and for the alternate use and
the amount of steam generated in excess of that required for steam
injection will affect the stack gas temperature. If the stack gas
temperature is reduced to too low a level, the amount of steam that
may be injected at low and at high ambient temperatures without the
formation of visible plume or acid condensate will be reduced. A
control signal derived from stack gas temperature sensor 96 should,
therefore, be used to generate an additional signal to control
voltage generator 92 contributing to bias voltage E.sub.O in the
same manner as humidity sensor 54 and interpolation circuit 59
contribute to signal E.sub.O in control voltage generator 51.
As an alternate to this modification, the stack gas temperature can
be raised and additional steam can be generated by the use of a
supplemental burner (not shown), that would be located between flow
splitter 91 and boiler 21.
Conditions may be encountered in which it is preferred to use a
source of steam, which employs some heat energy source for the
conversion of water to steam other than the turbine exhaust or
coolant streams. In such instances the source of steam may be
placed in flow communication with the combustor with a control
voltage generator of this invention being used either to adjust the
rate at which heat energy is provided for the steam generating
function (as in FIGS. 1 and 6) or to adjust the admission of steam
to the combustor (as in FIG. 7).
By utilizing the arrangements of the instant invention for
automatically controlling steam injection, very significant
improvements in performance resulting from optimized steam
injection may be achieved in varying degrees in conventional gas
turbines having fixed geometry components depending upon which
option is selected.
The control devices of this invention may be incorporated either
into existing machines or into new machines as described
herein.
* * * * *