JP2018048646A - Gas turbine installation - Google Patents

Abstract

PROBLEM TO BE SOLVED: To provide a gas turbine installation capable of stabilizing flames by keeping a combustor jet speed within a proper range even if a turbine load varies.SOLUTION: A gas turbine installation 10 according to the present invention comprises: a combustor 20 for burning fuel and an oxidant; a turbine 21 rotating with a combustion gas from the combustor 20; a heat exchanger 23 for cooling the combustion gas; a heat exchanger 24 for removing vapor from the combustion gas having passed through the heat exchanger 23 to obtain a dry work gas; and a compressor 25 for making the dry work gas into a supercritical fluid by raising the pressure. Further, the gas turbine installation comprises: piping 42 for guiding part of the dry work gas from the compressor 25 to the combustor 20 through the heat exchanger 23; piping 44 branching off from the piping 42 upstream from the heat exchanger 23 to discharge the part of the dry work gas to the outside; and piping 45 for introducing the rest of the dry work gas discharged from the compressor 25 into piping 40 coupling an exit of the turbine 21 and an entrance to the heat exchanger 23.SELECTED DRAWING: Figure 1

Description

  Embodiments described herein relate generally to gas turbine equipment.

  Increasing the efficiency of power plants is advancing due to demands such as carbon dioxide reduction and resource saving. Specifically, the working fluids of gas turbines and steam turbines are being actively heated and combined cycles are being promoted. Research and development is also underway for carbon dioxide recovery technology.

  FIG. 3 is a system diagram of a conventional gas turbine facility that circulates a part of carbon dioxide generated in a combustor as a working fluid. As shown in FIG. 3, the flow rate of oxygen separated from an air separator (not shown) is adjusted by a flow rate adjusting valve 310 and supplied to a combustor 311. The flow rate of the fuel is adjusted by the flow rate adjustment valve 312 and supplied to the combustor 311. This fuel is, for example, a hydrocarbon.

  The fuel and oxygen react (combust) in the combustor 311. When the fuel burns with oxygen, carbon dioxide and water vapor are generated as combustion gases. The flow rates of the fuel and oxygen are adjusted so as to obtain a stoichiometric mixture ratio (theoretical mixture ratio) in a state where they are completely mixed.

  Combustion gas generated by the combustor 311 is introduced into the turbine 313. The combustion gas that has performed expansion work in the turbine 313 passes through the heat exchanger 314 and further passes through the heat exchanger 315. When passing through the heat exchanger 315, the water vapor is condensed into water. Water is discharged outside through the pipe 316. Note that a generator 317 is connected to the turbine 313.

  The dry working gas (carbon dioxide) separated from the water vapor is pressurized by the compressor 318. A part of the boosted carbon dioxide is adjusted in flow rate by the flow rate adjusting valve 319 and discharged to the outside. The remainder of the carbon dioxide is heated in the heat exchanger 314 and supplied to the combustor 311.

  Here, in the gas turbine equipment, turbine load control is performed from full speed no load (FSNL) to a rating. As a result, the flow rate of the working fluid introduced into the turbine 313 changes. The pressure of the working fluid in this gas turbine equipment is high, and the volume flow rate of the working fluid in the compressor 318 is small. Therefore, an axial compressor is not suitable as the compressor 318, and a centrifugal compressor is used.

  A part of the carbon dioxide supplied to the combustor 311 is introduced into the combustion region together with fuel and oxygen. The remaining carbon dioxide is used for cooling the wall surface of the combustor 311 and diluting the combustion gas. The carbon dioxide introduced into the combustor 311 is introduced into the turbine 313 together with the combustion gas.

  In the system described above, carbon dioxide corresponding to the amount of carbon dioxide generated by burning fuel and oxygen in the combustor 311 is discharged to the outside of the system. The carbon dioxide discharged to the outside of the system is recovered by, for example, a recovery device. Also, for example, the discharged carbon dioxide can be used to push residual oil from underground rock formation in an oil field. On the other hand, carbon dioxide left in the system circulates in the system.

R.J.Allam, et al., High efficiency and low cost of electricity generation from fossil fuels while reducing atmospheric emissions, including carbon dioxide, Session 8, 11th International Conference on Greenhouse Gas Control Technology (GHGT-11)

  In the conventional gas turbine equipment described above, the flame formed in the combustor 311 is affected by, for example, the ejection speed of carbon dioxide ejected into the combustor 311 (hereinafter referred to as combustor ejection speed V). .

This combustor ejection speed V is defined by the following equation (1).
V = G × T × R × Z / (P × A) (1)

  Here, G is a volume flow rate of carbon dioxide flowing into the combustor 311, T is a temperature of carbon dioxide flowing into the combustor 311, R is a gas constant, and Z is a compression coefficient. P is the pressure of carbon dioxide flowing into the combustor 311, and A is the total opening area of the opening through which the carbon dioxide flowing into the combustor 311 passes.

  As described above, since the flame is affected by the combustor ejection speed V, when performing turbine load control in the gas turbine equipment, for example, by controlling the combustor ejection speed V to an appropriate range, It is preferable to improve the stability of the flame.

  However, the above-described centrifugal compressor used as the compressor 318 does not include inlet guide vanes such as an axial flow compressor, and it is difficult to perform a wide range of flow rate control. Therefore, it is difficult to control the combustor ejection speed V within an appropriate range when the turbine load changes.

  The problem to be solved by the present invention is to provide gas turbine equipment that can maintain flame combustor speed within an appropriate range and achieve flame stability even when the turbine load changes.

  A gas turbine facility according to an embodiment includes a combustor that burns fuel and an oxidant, a turbine that is rotated by the combustion gas discharged from the combustor, and a heat exchange that cools the combustion gas discharged from the turbine. And a water vapor remover that removes water vapor from the combustion gas that has passed through the heat exchanger and regenerates it into a dry working gas.

  Furthermore, the gas turbine equipment includes a compressor that pressurizes the dry working gas until it becomes a supercritical fluid, and a part of the dry working gas of the supercritical fluid discharged from the compressor through the heat exchanger. A combustor introduction pipe that leads to the combustor, and a discharge pipe that branches from the combustor introduction pipe upstream of the heat exchanger and discharges a part of the dry working gas flowing through the combustor introduction pipe to the outside. And a bypass pipe for introducing the remaining part of the dry working gas of the supercritical fluid discharged from the compressor into a pipe connecting the outlet of the turbine and the inlet of the heat exchanger.

It is a distribution diagram of gas turbine equipment of an embodiment. It is a figure which shows the relationship between the inlet pressure of the turbine in each load state, and the combustor ejection speed V in the gas turbine equipment of embodiment. It is a systematic diagram of the conventional gas turbine equipment which circulates a part of carbon dioxide produced | generated in the combustor as a working fluid.

  Hereinafter, embodiments of the present invention will be described with reference to the drawings.

  FIG. 1 is a system diagram of a gas turbine facility 10 according to an embodiment. As shown in FIG. 1, the gas turbine facility 10 includes a combustor 20 that burns fuel and an oxidant. A pipe 35 for supplying fuel to the combustor 20 is provided with a flow rate adjusting valve 15 for adjusting the flow rate of the fuel. The pipe 36 for supplying the oxidant to the combustor 20 is provided with a flow rate adjusting valve 16 for adjusting the flow rate of the oxidant. The flow rate adjustment valve 16 functions as an oxidant flow rate adjustment valve.

  Here, for example, natural gas, hydrocarbons such as methane, coal gasification gas, or the like is used as the fuel. Oxygen is used as the oxidizing agent. This oxygen is obtained, for example, by being separated from the atmosphere by an air separation device (not shown).

  The combustion gas discharged from the combustor 20 is guided to the turbine 21. The turbine 21 is rotated by the combustion gas. For example, a generator 22 is connected to the turbine 21. Note that the combustion gas discharged from the combustor 20 here is a combustion product generated by combustion of fuel and oxidant, and is supplied to the combustor 20 from the combustor 20 together with the combustion product. It contains exhaust gas (carbon dioxide) to be discharged, which will be described later.

  The combustion gas discharged from the turbine 21 is cooled by passing through the heat exchanger 23 interposed in the pipe 40. The combustion gas that has passed through the heat exchanger 23 further passes through the heat exchanger 24 interposed in the pipe 40. When the combustion gas passes through the heat exchanger 24, water vapor contained in the combustion gas is removed and regenerated into a dry working gas. Here, the water vapor condenses into water by passing through the heat exchanger 24. This water is discharged to the outside through the pipe 41, for example. The heat exchanger 24 functions as a water vapor remover that removes water vapor.

  It is preferable that no surplus oxidant (oxygen) and fuel remain in the combustion gas discharged from the combustor 20. Therefore, the flow rates of the fuel and oxygen supplied to the combustor 20 are adjusted to be a stoichiometric mixture ratio (equivalence ratio 1). Therefore, the component of the dry working gas is almost carbon dioxide. The dry working gas includes, for example, a case where a small amount of carbon monoxide is mixed.

  The dry working gas is guided to the compressor 25 by the pipe 40. The dry working gas is pressurized by the compressor 25 until it becomes a supercritical fluid. At the outlet of the compressor 25, the pressure of the dry working gas is, for example, 8 MPa to 9 MPa, and the temperature of the dry working gas is, for example, 35 to 45 ° C. The supercritical fluid refers to a state under temperature and pressure above the critical point.

  Here, as the compressor 25, for example, a centrifugal compressor is used. For example, the compressor 25 is coaxially connected to the turbine 21 in order to prevent overspeed of the turbine 21. In this case, the compressor 25 rotates at a constant rotational speed of the turbine 21 when the turbine 21 is rated. Since the centrifugal compressor has a small surge margin with respect to an increase in pressure ratio, it is preferable to operate at a constant volume flow rate and pressure ratio when the rotation speed is constant.

  In order to maintain the pressure at the outlet of the compressor 25 at, for example, a constant supercritical pressure, the pressure at the inlet of the compressor 25 also has a constant value. A constant pressure at the inlet of the compressor 25 is preferable from the viewpoint of sealing characteristics of the turbine 21 and stable use of the heat exchangers 23 and 24 because the pressure at the outlet of the turbine 21 is constant. In order to keep the pressure at the outlet of the compressor 25 constant, it is necessary to adjust the flow rate of the dry working gas flowing in the pipe 45 described later.

  A part of the supercritical fluid dry working gas discharged from the compressor 25 is led to the combustor 20 through the pipe 42. This pipe 42 functions as a combustor introduction pipe. A cooler 26 for cooling the supercritical fluid dry working gas is interposed in the pipe 42. The dry working gas of the supercritical fluid passes through the cooler 26 and becomes a temperature lower than the critical point temperature while maintaining a pressure higher than the critical point pressure. Therefore, after passing through the cooler 26, the dry working gas leaves the supercritical fluid state and becomes liquid.

  A pump 27 that pressurizes the dry working gas that has become liquid is interposed in the pipe 42 on the downstream side of the cooler 26. The pump 27 boosts the dry working gas that has become liquid, for example, according to the turbine load. The rotation speed of the pump 27 is controlled by, for example, an inverter motor. The dry working gas that has become liquid is boosted by the pump 27, and the temperature also exceeds the critical point temperature. Therefore, the dry working gas that has become liquid passes through the pump 27 and becomes the dry working gas of the supercritical fluid again.

  In the pump 27, for example, in order to supply a dry working gas having a predetermined flow rate and pressure to the combustor 20, the rotational speed control is performed by an inverter so as to pass through a set point of the predetermined flow rate and pressure, for example.

  Here, the dry working gas that has passed through the cooler 26 is made liquid while maintaining a pressure higher than the critical point pressure, for example, under conditions where gas and liquid can coexist, such as under the critical point condition. This is to avoid damage due to cavitation that occurs when a two-layer flow of gas-liquid mixing enters the pump 27. Further, by using a liquid, it is possible to operate while maintaining cycle efficiency without taking heat of condensation.

Moreover, the flow rate of the dry working gas discharged from the pump 27 and the outlet pressure of the pump 27 vary widely by the turbine load control. Since combustion gas becomes a choke flow in the turbine 21, the Swallowing Capacity (SWC) is constant, and therefore, the following equation (2) is satisfied.
SWC = G _t × (T _t ) ^1/2 / P _t = constant (Expression (2)

Here, G _t is the volume flow rate of the combustion gas at the inlet of the turbine 21, T _t is the temperature of the combustion gas at the inlet of the turbine 21, and P _t is the pressure of the combustion gas at the inlet of the turbine 21.

  For example, in order to increase the pressure of the combustion gas supplied to the turbine 21, when the flow rate of the combustion gas is determined, the fuel flow rate and the oxidant flow rate are increased to raise the temperature of the combustion gas. However, when the pump 27 is not provided, there is almost no surge pressure margin of the centrifugal compressor which is the compressor 25, so that the pressure rise cannot be endured. Therefore, by providing the pump 27, a system that can withstand the above-described pressure rise is realized.

  From the pipe 42 between the pump 27 and the heat exchanger 23, a pipe 44 for discharging a part of the dry working gas flowing through the pipe 42 to the outside is branched. This pipe 44 functions as a discharge pipe. The pipe 44 is provided with a flow rate adjustment valve 29 for adjusting the flow rate of the dry working gas to be discharged. The flow rate adjustment valve 29 functions as a discharge flow rate adjustment valve.

  The dry working gas discharged from the pipe 44 is recovered by, for example, a recovery device. Also, for example, the discharged dry working gas can be used to push residual oil out of the oil field underground rock formation. For example, carbon dioxide corresponding to the amount of carbon dioxide generated by burning fuel and oxygen in the combustor 20 is discharged from the pipe 44. The dry working gas discharged from the pipe 44 is introduced into the combustor 20 and circulated in the system.

  Downstream of the branch portion of the pipe 44, the pipe 42 passes through the heat exchanger 23 and communicates with the combustor 20. The supercritical fluid dry working gas flowing through the pipe 42 is heated in the heat exchanger 23 by obtaining heat from the combustion gas discharged from the turbine 21. The dry working gas introduced into the combustor 20 through the pipe 42 is ejected from the upstream side of the combustor 20 into the combustion region together with fuel and oxidant, or from the dilution hole or the like after the combustor liner is cooled. Injected downstream of the combustion region in the liner.

  Here, it is preferable that the ejection speed of the dry working gas guided to the combustor 20 via the pipe 42 to the combustor 20 is substantially constant regardless of the turbine load. The ejection speed is the combustor ejection speed V defined by the above-described equation (1). This combustor ejection speed V is set so that the recirculation region contributing to flame stability is formed within an appropriate range of the combustion region. The combustor ejection speed V being substantially constant means, for example, a range of ± 10% around the average combustor ejection speed at each turbine load.

  Since the total opening area A of the opening through which the dry working gas (carbon dioxide) flowing into the combustor 20 passes is constant, if the combustor ejection speed V is set to be almost constant regardless of the turbine load, The mass flow rate of the dry working gas supplied to the combustor varies, but the volume flow rate becomes substantially constant regardless of the turbine load.

  The remainder of the supercritical fluid dry working gas discharged from the compressor 25 passes through the pipe 45 and is introduced into the pipe 40 that connects the outlet of the turbine 21 and the inlet of the heat exchanger 23. The pipe 45 functions as a bypass pipe. The pipe 45 is provided with a flow rate adjusting valve 30 for adjusting the flow rate of the dry working gas of the supercritical fluid introduced into the pipe 40. In order to keep the rotation speed of the compressor 25 constant and the pressure at the outlet of the compressor 25 constant, the pressure at the inlet of the compressor 25 needs to be constant. Therefore, the flow rate of the dry working gas to be bypassed is adjusted by the flow rate adjustment valve 30. The flow rate adjustment valve 30 functions as a bypass flow rate adjustment valve.

  Further, the gas turbine equipment 10 detects the flow rate of the fuel flowing through the pipe 35, the flow rate detection unit 51 detecting the flow rate of the oxidant flowing through the pipe 36, and the flow rate of the dry working gas flowing through the pipe 42. A flow rate detection unit 52 that detects the flow rate of the dry working gas that flows through the pipe 45, and a flow rate detection unit that detects the flow rate of the dry working gas that flows through the pipe 45. Each flow rate detection unit is configured by a flow meter such as a venturi type or a Coriolis type, for example.

  Here, the flow rate detection unit 50 is a fuel flow rate detection unit, the flow rate detection unit 51 is an oxidant flow rate detection unit, the flow rate detection unit 52 is a combustor introduction flow rate detection unit, and the flow rate detection unit 53 is an exhaust flow rate. As a detection unit, the flow rate detection unit 54 functions as a bypass flow rate detection unit.

  The gas turbine equipment 10 includes a control unit 60 that controls the opening degree of each flow rate adjustment valve 16, 29, 30 based on the detection signal from each flow rate detection unit 50, 51, 52, 53, 54 described above. Yes. The control unit 60 mainly includes, for example, an arithmetic unit (CPU), storage means such as a read only memory (ROM) and random access memory (RAM), input / output means, and the like. In the CPU, for example, various arithmetic processes are executed using a program or data stored in the storage means.

  The input / output means inputs an electric signal from an external device or outputs an electric signal to the external device. Specifically, the input / output means is connected to, for example, each flow rate detection unit 50, 51, 52, 53, 54, each flow rate adjustment valve 15, 16, 29, 30 or the like so as to be able to input and output various signals. Yes. The processing executed by the control unit 60 is realized by a computer device, for example.

  Next, the operation | movement which concerns on flow volume adjustment of the fuel, oxygen, and dry working gas (carbon dioxide) supplied to the combustor 20 is demonstrated with reference to FIG.

  During operation of the gas turbine equipment 10, the control unit 60 inputs an output signal from the flow rate detection unit 50 through the input / output means. Based on the input output signal, an oxygen flow rate necessary for setting the equivalence ratio to 1 is calculated in the arithmetic unit using a program or data stored in the storage means. The fuel flow rate is controlled, for example, by adjusting the valve opening degree of the flow rate adjustment valve 15 based on the required gas turbine output.

  Subsequently, the control unit 60 outputs an output signal for adjusting the valve opening so that the calculated oxygen flow rate flows into the pipe 36 based on the output signal from the flow rate detection unit 51 input from the input / output means. Output from the input / output means to the flow rate adjustment valve 16.

  Subsequently, in the arithmetic unit of the control unit 60, based on the output signal from the flow rate detection unit 50 inputted from the input / output means, the flow rate of the dry working gas (carbon dioxide) of the supercritical fluid introduced into the combustor 20, The flow rate of the dry working gas of the supercritical fluid discharged from the pipe 44 and the flow rate of the dry working gas of the supercritical fluid bypassed through the pipe 45 are calculated. The calculation of the flow rate may be performed simultaneously with the calculation of the oxygen flow rate described above. Also, the flow rate of the dry working gas can be calculated based on the output signal from the flow rate detection unit 51.

  Here, the flow rate of the dry working gas (carbon dioxide) introduced into the combustor 20 is calculated so that the combustor ejection speed V becomes a set value. Note that the flow rate of the dry working gas discharged from the pipe 44 is equivalent to the amount of carbon dioxide generated by burning the fuel and oxygen in the combustor 20 as described above. For example, when the fuel flow rate decreases, the flow rate of the dry working gas that is bypassed through the pipe 45 increases. On the other hand, when the fuel flow rate increases, the flow rate of the dry working gas that is bypassed through the pipe 45 decreases.

  In addition, since the compressor 25 is coaxially connected with the turbine 21, when the turbine 21 is rated, the compressor 25 rotates at a constant rotational speed of the turbine 21. Further, since the pressure at the inlet of the compressor 25 is constant and the pressure of the dry working gas at the outlet of the compressor 25 is a constant supercritical pressure, the flow rate of the dry working gas discharged from the compressor 25 is constant. .

  Subsequently, the control unit 60 calculates the flow rate of the dry working gas, which is calculated based on the output signals from the flow rate detection units 52, 53, and 54 input from the input / output means, to the respective pipes 42, 44, and 45. As described above, an output signal for adjusting the valve opening is output from the input / output means to the flow rate adjusting valves 29 and 30. In the configuration shown in FIG. 1, the flow rate detection unit 52 detects the flow rate of the dry working gas introduced into the combustor 20 and the dry working gas discharged from the pipe 44.

  Here, the pump 27 is controlled by the control unit 60 to a rotational speed at which the flow rates of the dry working gas introduced into the combustor 20 and the dry working gas discharged from the pipe 44 can be drawn. Further, the pressure of the dry working gas at the outlet of the pump 27 is a pressure required at the inlet of the combustor 20, in other words, at the inlet of the turbine 21.

  Here, for example, when the flow rate of the dry working gas introduced into the combustor 20 is decreased, the control unit 60 controls the flow rate adjustment valve 30, for example.

  Then, the dry working gas flowing in the pipe 42 branched to the pipe 44 is introduced into the combustor 20 through the heat exchanger 23.

  By performing the control as described above, the combustor ejection speed V can be maintained substantially constant within an appropriate range even when the turbine load changes. Thus, the recirculation region is formed in an appropriate range of the combustion region, and flame stabilization in the combustor 20 can be achieved.

  Here, FIG. 2 is a diagram illustrating a relationship between the inlet pressure of the turbine 21 and the combustor ejection speed V in each load state in the gas turbine equipment 10 of the embodiment. Note that the outlet pressure of the turbine 21 in the example is 3 MPa. In FIG. 2, for example, FSNL is a full-speed no-load state, and 25% indicates that the turbine load is 25%.

  As shown in FIG. 2, even when the turbine load changes, the combustor ejection speed V is maintained substantially constant.

  As described above, according to the gas turbine equipment 10 of the embodiment, the pressure of the dry working gas at the outlet of the compressor 25 is set to a constant supercritical pressure, the pipe 42 is provided with the pump 27, and the dry working gas A pipe 45 that bypasses a part of the pipe 40 is provided. Thus, even when the turbine load changes, the combustor ejection speed V can be maintained substantially constant within an appropriate range, and flame stabilization in the combustor 20 can be achieved.

  According to the embodiment described above, even when the turbine load changes, it is possible to maintain the combustor ejection speed within an appropriate range and achieve flame stability.

  Although several embodiments of the present invention have been described, these embodiments are presented by way of example and are not intended to limit the scope of the invention. These novel embodiments can be implemented in various other forms, and various omissions, replacements, and changes can be made without departing from the scope of the invention. These embodiments and modifications thereof are included in the scope and gist of the invention, and are included in the invention described in the claims and the equivalents thereof.

  DESCRIPTION OF SYMBOLS 10 ... Gas turbine equipment, 15, 16, 29, 30 ... Flow control valve, 20 ... Combustor, 21 ... Turbine, 22 ... Generator, 23, 24 ... Heat exchanger, 25 ... Compressor, 26 ... Cooler, 27 ... Pump, 35, 36, 40, 41, 42, 44, 45 ... Piping, 50, 51, 52, 53, 54 ... Flow rate detection unit, 60 ... Control unit.

Claims (10)

Gas turbine equipment,
A combustor configured to burn fuel and oxidant;
A turbine configured to be rotated by combustion gas discharged from the combustor;
A heat exchanger configured to cool the combustion gas discharged from the turbine;
A water vapor remover configured to remove water vapor from the combustion gas that has passed through the heat exchanger and regenerate it into a dry working gas;
A pump configured to increase the pressure of the dry working gas, wherein the rotational speed of the pump is such that the rotational speed of the turbine and the flow rate and pressure of the dry working gas directed to the heat exchanger are changed. Are independently controlled with the pump,
A combustor inlet tube configured to direct a portion of the dry working gas through the heat exchanger to the combustor;
A gas turbine facility comprising:   The gas turbine equipment further includes a compressor configured to increase the pressure of the dry working gas until it becomes a supercritical fluid, and the combustor introduction pipe performs dry operation from the compressor as a supercritical fluid. The gas turbine equipment of claim 1, wherein the gas turbine equipment receives a portion of the gas.   The gas turbine equipment according to claim 2, wherein the compressor comprises a centrifugal compressor connected coaxially with the turbine.   The exhaust pipe further comprising a discharge pipe branched from a combustor introduction pipe on the upstream side of the heat exchanger and configured to discharge a part of the dry working gas flowing through the combustor introduction pipe to the outside. The gas turbine equipment described in 1.   The apparatus further comprises a cooler disposed in a combustor introduction pipe upstream of the branch of the exhaust pipe and configured to cool a dry working gas of a supercritical fluid flowing through the combustor introduction pipe. 4. The gas turbine equipment according to 4.   The pump is disposed in a combustor introduction pipe between the branch of the exhaust pipe and the cooler, and increases the pressure of the dry working gas flowing through the combustor introduction pipe according to a turbine load. Item 6. The gas turbine equipment according to Item 5.   5. The apparatus according to claim 4, further comprising a bypass pipe configured to introduce a remaining portion of the dry working gas discharged from the compressor into a pipe connecting an outlet of the turbine and an inlet of the heat exchanger. Gas turbine equipment. A fuel flow rate detector arranged in a pipe through which the fuel supplied to the combustor flows and configured to detect the flow rate of the fuel;
An oxidant flow rate detection unit arranged in a pipe through which the oxidant supplied to the combustor flows and configured to detect the flow rate of the oxidant;
An oxidant flow rate adjusting valve provided in a pipe through which the oxidant flows and configured to adjust the flow rate of the oxidant;
A combustor introduction flow rate detector arranged in the combustor introduction tube and configured to detect a flow rate of a dry working gas of a supercritical fluid flowing through the combustor introduction tube;
An exhaust flow rate detector arranged in the exhaust pipe and configured to detect the flow rate of the dry working gas of the supercritical fluid flowing through the exhaust pipe;
An exhaust flow rate adjusting valve provided in the exhaust pipe and configured to adjust the flow rate of the dry working gas of the supercritical fluid flowing through the exhaust pipe;
A bypass flow rate detector arranged in the bypass pipe and configured to detect the flow rate of the dry working gas of the supercritical fluid flowing through the bypass pipe;
A bypass flow rate adjusting valve provided in the bypass pipe and configured to adjust the flow rate of the dry working gas of the supercritical fluid flowing through the bypass pipe;
Based on detection signals from the fuel flow rate detection unit, the oxidant flow rate detection unit, the combustor introduction flow rate detection unit, the exhaust flow rate detection unit, and the bypass flow rate detection unit, the oxidant flow rate adjustment valve, the discharge A flow rate adjusting valve, and a control unit configured to control the opening degree of the bypass flow rate adjusting valve;
The gas turbine equipment according to claim 7, further comprising:   The gas turbine equipment according to claim 7, further comprising a bypass flow rate adjusting valve provided in the bypass pipe and configured to adjust a flow rate of the dry working gas flowing through the bypass pipe.   The gas turbine installation of claim 9, wherein the bypass flow regulating valve is configured to provide a constant volume flow of the dry working gas to the compressor.

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