GAS TURBINE PLANT

TECHNICAL FIELD

The present invention relates to a method of controlling emissions of a gas turbine plant and to a gas turbine plant.

BACKGROUND ART

As known, controlling polluting emissions is an objective of primary importance in the making of any type of thermal machine, and in particular of gas turbines used for the production of electricity. Indeed, the increased awareness of environmental risks moves towards regulations which impose increasingly more restrictive limits.

Containing emissions is particularly critical when the thermal machines operate in low load conditions, because the machines are optimized to deliver higher powers. Critical conditions occur, for example, during the night, when the gas turbines operate in technical minimum environmental conditions because the energy demand is very low. Such a management provides the economic advantage to the plant user to be able to respond to sudden requests from the power grid with low fuel consumption, but on the other hand regulations require to maintain emissions within an authorized limit value. One of the problems to be faced to abate polluting emissions in efficient manner is maintaining optimal working conditions, which allow the complete oxidation of the carbon contained in the fuel. If combustion conditions are not ideal and sufficient energy is not reached, a fraction of the available carbon is only partially oxidized and produces carbon monoxide (CO) .

On the other hand, the amount of CO which may be emitted into the environment is limited by severe environmental regulations. The need to respect the set limits very often forces to set power references for the turbines which are higher than the technical mechanical minimum of the machine also when the actually requested load is lower. In this manner, the combustion temperature increases and the available, incompletely oxidized carbon fraction and the amount of produced CO are reduced as a consequence. Although the solution allows to respect the legal limits, there is a greater consumption of fuel and an excess of produced energy with respect to real needs.

Combustion in non-optimal conditions, which correspond to the production of CO, also has negative effects on thermal machine efficiency. Indeed, the CO molecule, in which the carbon is only partially oxidized, still contains available energy which could be released by complete oxidation (with production of CO ₂ ) . Instead, the available energy is introduced into the environment with the exhaust fumes and cannot be exploited by the gas turbine. The efficiency of the machine is thus reduced.

DISCLOSURE OF INVENTION

It is thus the object of the present invention to provide a method for controlling emissions of a gas turbine plant and a gas turbine plant which allow to overcome, or at least attenuate, the described limitations.

According to the present invention, a method of controlling emissions of a gas turbine plant and a gas turbine plant are provided as disclosed in claims 1 and 8, respectively .

BRIEF DESCRIPTION OF THE DRAWINGS

The present invention will now be described with reference to the accompanying drawings, which illustrate some non-limitative embodiments thereof, in which:

- figure 1 is a simplified block diagram of a gas turbine plant in accordance with an embodiment of the present invention;

- figure 2 is a more detailed block diagram of a control device incorporated in the gas turbine plant in figure 1 ;

- figure 3 is a diagram which shows first quantities related to the plant in figure 1 and to the control device in figure 2; - figure 4 is a more detailed block diagram of a control device incorporated in the gas turbine plant in figure 1 according to a variant of the invention; and

- figure 5 is a diagram which shows second quantities related to the plant in figure 1 and to the control device in figure 4.

BEST MODE FOR CARRYING OUT THE INVENTION

With reference to figure 1, a plant for the production of electricity, indicated by reference numeral 1 as a whole, comprises a gas turbine assembly 2, an alternator 3, coupled to the same shaft 4, and an emission control device 5, in particular of carbon monoxide (CO) , and a heat exchanger 6, cooperating with the emission control device 5.

The gas turbine assembly 2 comprises a compressor 7, which aspirates an air flow Q _A from the outside through an intake pipe 8, a combustion chamber 9 and a turbine 10, coupled to the combustion chamber 9 to receive and expand the exhaust-gas flow Q _E . An exhaust pipe 11, downstream of the turbine 10, receives and evacuates an exhaust-gas flow Q _E produced by the gas turbine assembly 2.

The compressor 7 is of the axial multistage type and is provided with an adjustable inlet guide vane or IGV stage 7a. The orientation of the vanes of the IGV stage 7a is determined by an IGV actuator 12 which receives an IGV regulation signal S IGV from a general plant controller 100, not described in detail herein.

The air flow Q _A aspirated by the compressor 7 is conveyed through the intake pipe 8, along which a filter 8a and a conditioning chamber 8b are arranged, and processed by the compressor 7. The air flow Q _A is introduced into the combustion chamber 9. A fuel gas flow Q _F is added to the air flow Q _A and the resulting mixture is burnt, producing the exhaust-gas flow Q _E .

The fuel gas flow Q _F is injected by a fuel supply line

15 and a fuel supply valve 16 controlled by the general plant controller 100, through a fuel regulation signal S _FV . In an embodiment, the fuel gas flow Q _F is measured by a flow measuring device 14 which supplies a flow signal S _F .

Upstream of the fuel supply valve, 16, the fuel supply line 15 crosses the heat exchanger 6, which is controlled by the emission control device 5 to adjust the temperature of the fuel flow Q _F delivered to the combustion chamber 9. The heat exchanger 6 may be either dedicated to fuel temperature regulation or also shared for other functions. Advantageously, in an embodiment, the heat exchanger 6 is incorporated in a fuel gas pressure reduction system 17. The fuel gas pressure reduction system 17 is an auxiliary system which allows to adapt the pressure and the temperature of the fuel gas coming from a distribution source 18, e.g. a methane pipeline, to the needs of the thermal machine, in particular of the gas turbine plant 2. In particular, the fuel gas pressure reduction system 17 uses regulation valves (not shown) to reduce and control the fuel pressure coming from the distribution source 18. The reduction of the gas pressure, for example obtained by expansion, causes a lowering of the temperature. The heat exchanger 6 allows to supply heat to the expanded gas, adjusting the temperature so as to optimize the combustion conditions.

The thermal energy is controlled by a heating regulation valve 20, which determines a heating fluid flow QH let into the heat exchanger 6. In turn, the heating regulation valve 20 is operated by the emission control device 5 through a heating regulation signal SH, as explained in detail below.

The emission control device 5 comprises a processing unit 22 and a sensor assembly 23, arranged in the exhaust pipe 11 of the turbine 10, so as to receive the exhaust gas flow. In particular, the sensor assembly 23 comprises an oxygen sensor 25, for example a lambda sensor, providing an oxygen concentration signal S ₀ 2 , indicating the residual oxygen concentration O2 in the exhaust-gas flow Q _E . Furthermore, the sensor assembly 23 may comprise detection cells for measuring the concentrations of carbon monoxide (CO) and of nitrogen oxides (NOx) , temperature sensors and pressure sensors.

In an embodiment, the processing unit 22 is a PLC (Programmable Logic Controller) and is coupled to the sensor assembly 23 to receive measuring signals, including the oxygen concentration signal S ₀ 2 supplied by the oxygen concentration sensor 25. In a different embodiment, the processing unit 22 is incorporated in the general plant controller 100 of the plant 1.

Furthermore, the processing unit 22 may receive a CO concentration signal S _C o from the sensor assembly 23; a position signal IGV S _IGV , indicating the current position of the vanes of the IGV stage 7a, and a load signal S _G TP , indicating the power supplied by the gas turbine 10, from the general plant controller 100; and a temperature reference S _T , set by the fuel gas pressure reduction system 17 (alternatively, the temperature reference S _T may be determined directly by the processing unit 22, e.g. according to the position signal IGV S _IGV , and to the load signal S _G TP ) ·

The processing unit 22 is configured to determine the heating regulation signal S _H according to the oxygen concentration signal S ₀ 2 ·

With reference to figure 2, in an embodiment, the processing unit comprises an enable stage 26, a regulation stage 27, and a processing stage 28.

The enable stage 26 is configured to activate and deactivate the regulation stage 27 as a function of the operating conditions of the gas turbine assembly 2, in particular as a function of the CO concentration (available by means of the CO concentration signal S _C o ) and of the position of the vanes of the IGV stage 7a (available by means of the IGV position signal S IGV) · The enable stage 26 comprises two threshold comparators 30, 31, a logical port 32 and a selector module 33.

The threshold comparator 30 receives the CO concentration signal S _C o in input and delivers a comparison signal S _T m having a first logical value, when the CO concentration signal S _C o is higher than a concentration threshold ΊΕ _∞ , and a second logical value in the opposite case .

The threshold comparator 31 receives the IGV position signal S IGV in input and delivers a comparison signal S _T H2 having a first logical value, when the IGV position signal S IGV is lower than an opening threshold ΊΕ _{τ ν} , and a second logical value in the opposite case.

The logical port 32 delivers an enable signal S EN as a function of the comparison signals S _T HI , S _T H2 · In particular, the logical port 32 is configured so that the enable signal S E has an enable value when, according to the comparison signals S _TH I, S _TH 2, the CO concentration signal S _C o is higher than a CO concentration threshold TH _C o and the position signal IGV S _IGV is lower than the opening threshold ΊΕ _{τ ν} , and a disable value otherwise.

The selector module 33 is controlled by the enable signal. In detail, the selector module 33 delivers the output of the regulation stage 27 to the processing stage 28 when the enable signal EN has the enable value, and a neutral control value, for example zero value, when the enable signal EN has the disable value.

The regulation stage 27 uses the heating regulation signal S _H as control variable to maintain the residual oxygen concentration O2 (controlled variable) in the exhaust gases at a reference value. The residual oxygen concentration O2 represents the combustion conditions. In particular, the power supplied by the gas turbine assembly 2 being equal, the residual oxygen concentration O2 is higher the lower is the degree of carbon oxidation present in the fuel gas, and consequently higher is the CO concentration in the exhaust fumes. An increase of the fuel gas temperature determines a corresponding increase of the energy in the combustion chamber 9 and the complete oxidation of a greater fraction of the available carbon.

In an embodiment, the regulation stage 27 comprises a reference generator module 35, a comparator 36, a normalizer module 37 and a regulator module 38.

The reference generator module 35 provides a reference concentration value S ₀ 2 _R for the residual oxygen concentration O2 in the exhaust gases according to the load signal S _GTP ^ indicating the power supplied by the gas turbine assembly 2, and a characteristic function Fl, shown by way of example in figure 3. The characteristic function Fl indicates the residual oxygen concentration O2 as the power P supplied by the gas turbine 10 varies and is determined by the construction features of the gas turbine assembly 2. The reference generator module 35 may comprise, for example, a table representing the characteristic function Fl, which is determined during the step of designing of the gas turbine assembly 2.

In an alternative embodiment (figure 4), a reference concentration value S ₀ 2 _R ' may be delivered by a reference generator module 35' according to the measured fuel gas flow Q _F (using the flow signal S _F ) and a characteristic function F2, shown by way of example in figure 5. The characteristic function F2 indicates the residual oxygen concentration O2 as the exhaust-gas flow Q _E varies. The reference generator module 35' may comprise, for example, a table representing the characteristic function F2.

With reference again to figure 2, the comparator 36 receives the reference concentration value S ₀ 2 _R and the oxygen concentration signal S ₀ 2 and determines an error signal E ₀ 2 from the difference between the oxygen concentration signal S ₀ 2 and the reference concentration value So2R- The normalizer module 37 receives the error signal E ₀ 2 from the comparator 36 and supplies a normalized error signal E ₀ 2 to the regulator module 38.

The regulator module 38 is configured to determine a correction coefficient K _c which, applied to the temperature reference S _T set by the fuel gas pressure reduction system 17, tends to cancel or reduce the error signal E ₀ 2 , taking the actual residual oxygen concentration O2 to the reference concentration value S ₀ 2R- By way of non-limiting example, in an embodiment, the regulator module 38 includes a proportional-integral type regulator.

The processing stage 28 is configured to generate a heating control signal S _H by combining the temperature reference S _T and the control value delivered by the selector module 33 of the enable stage 26 (i.e. the zero value or the correction coefficient K _c in presence of the deactivation value and of the enable value of the enable signal EN , respectively) . In practice, when the regulation stage 27 is disabled, the processing stage 28 receives the neutral control value, which does not change the general control action of the plant. Instead, when the regulation stage 27 is enabled, the processing stage 28 applies the correction coefficient K _c to modify the temperature reference S _T .

In an embodiment, in particular, the correction coefficient KC is an additive coefficient. In this case, the processing stage 28 comprises an adder module 40, downstream of which a limiter module 41 is placed. The adder module 40 adds the control value receive from the selector module 33 and the temperature reference S _T . The signal thus formed is delivered to the limiter module 41, to be limited to values compatible with the fuel gas pressure reduction system 17. The output of the limiter module 41 defines the heating regulation signal S _H .

In practice, the emission control device 5 intervenes at low loads, when criticalities are detected in the CO concentrations in exhaust and the general plant controller has no margin to decrease the air flow Q _A delivered to the combustion chamber (i.e. when the vanes of the IGV stage 7a cannot be closed any further) . In this case, the heating regulation signal S _H determines an increase of the temperature reference S _T for the fuel gas pressure reduction system 17, which, through the heat exchanger 6, in turn, produces an increase of the fuel gas temperature introduced into the combustion chamber. As mentioned above, this temperature increase reduces the incompletely oxidized carbon fraction present in the exhaust gases, and consequently abates CO emissions. Furthermore, the available energy is exploited more completely during combustion .

The invention thus allows to contain CO emissions so as to satisfy the stringent constraints set by standards, in particular for loads close to the technical environmental minimum, while the efficiency of the gas turbine assembly is increased.

An advantage of the invention derives from the use of the residual oxygen concentration O ₂ as controlled variable in the CO emission abatement process. Indeed, a control based on the residual oxygen concentration O ₂ benefits from a substantial immunity to interfering substances present in the exhaust gases, and is thus more accurate. On the contrary, the CO concentration measurements may be alternated with the presence of aqueous vapor in the exhaust fumes. A control based directly on the CO concentration would thus suffer from more significant error margins.

It is finally apparent that changes and variations can be made to the described method and plant without departing from the scope of protection of the present invention as defined in the appended claims.