JP5822608B2 - MONITORING DEVICE AND METHOD, PROGRAM, GAS TURBINE EQUIPMENT HAVING THE SAME, AND GAS TURBINE MONITORING SYSTEM - Google Patents

Description

  The present invention relates to a monitoring apparatus and method, a program, a gas turbine facility including the same, and a gas turbine monitoring system.

In a general gas turbine power plant, a gas turbine includes a compressor, a combustor, a turbine, and a generator, and air that has been pressurized in the compressor and fuel gas that has been heated to a high temperature by a heat exchanger. It is sent to a combustor and burns, and a turbine is driven by the combustion gas to operate a generator. Further, cooling air is extracted from the compressor, and the turbine side is cooled by the extracted cooling air. Conventionally, it is known that such a gas turbine can determine the gas turbine performance based on the flow rate of air flowing into the compressor, the efficiency of the compressor, the flow rate of cooling air for cooling the turbine, the turbine efficiency, and the like.
For example, in Patent Document 1, the compressor efficiency is calculated based on the compressor inlet temperature, the compressor inlet pressure, the compressor outlet temperature, and the compressor outlet pressure, and the calculated compressor efficiency is rated. Has been proposed to determine compressor damage and monitor compressor efficiency.

Japanese Patent Laid-Open No. 11-257240

  However, the method of Patent Document 1 has a problem that even if the compressor efficiency can be monitored, the flow rate of the turbine cooling air and the turbine efficiency cannot be grasped, so that the gas turbine performance cannot be determined correctly. The turbine efficiency calculation requires information on the turbine inlet temperature, but the turbine inlet temperature is approximately 1400 ° C, which cannot be handled by ordinary thermocouples, so a special thermocouple is required, increasing costs. There was a problem to do. Alternatively, the turbine inlet temperature is adjusted by calculating the heat balance, which is the state quantity of the inlet / outlet of each device of the gas turbine, without measuring the turbine inlet temperature, and the turbine efficiency is determined based on the obtained turbine inlet temperature information. However, the heat balance calculation requires a lot of parameters, and there is a problem that the calculation takes time.

  The present invention has been made in view of such circumstances, and a monitoring apparatus and method, a program, and a gas turbine provided with the same that can easily calculate the amount of change in turbine efficiency without special measurement equipment. An object is to provide a facility and a gas turbine monitoring system.

In order to solve the above problems, the present invention employs the following means.
In the present invention, the intake air supplied from the inlet side of the compressor is compressed in the compressor to become compressed air, supplied to the turbine through the combustor, and cooling air for cooling the turbine extracted from the compressor A monitoring device applied to a gas turbine supplied to a turbine, wherein a change in compressor flow rate, which is a flow rate change amount of the intake air on the inlet side of the compressor, and a change in efficiency of the compressor in a predetermined period compressor efficiency change amount is an amount, before Symbol turbine cooling air quantity variation is the flow rate variation of the cooling air inlet side of the turbine, and the calculating the gas turbine output change amount which is the amount of change of the gas turbine output a first calculating means, the compressor flow rate change amount obtained by multiplying the respective weighting factor for the gas turbine output change amount, and the compressor efficiency variation, the turbine cooling air Each of the sum of the amount of change by subtracting from the gas turbine output change amount to provide a monitoring device and a second calculating means for calculating a turbine efficiency change amount.

According to such a configuration, the compressor flow rate change amount, the compressor efficiency change amount, and the turbine cooling air amount change amount for a predetermined period supplied from the inlet side of the compressor are calculated, and based on these change amounts, A turbine efficiency change amount is calculated.
Thereby, even if there is no special measuring device which measures the turbine inlet temperature required for calculating the turbine efficiency, the turbine efficiency can be calculated easily. In addition, since the turbine efficiency is calculated based on the compressor flow rate change amount, the compressor efficiency change amount, and the turbine cooling air amount change amount during the predetermined period, the time for calculating the turbine efficiency can be shortened. In addition, by calculating the amount of change in turbine efficiency in this way, the state of the gap (tip clearance) between the turbine blade tip (tip) and the stationary blade, turbine wear (including melting), deposit (foreign matter) ), An increase in exhaust-side pressure loss, damage to the diffuser, and the like.
More specifically, the second calculation means includes the compressor flow rate change amount obtained by multiplying each weighting factor for the gas turbine output change amount, which is a change amount of the gas turbine output during a predetermined period, and the compressor efficiency. and variation, each of the sum of said turbine cooling air quantity change amount is subtracted from the gas turbine output change amount, you calculate the turbine efficiency change amount.
As described above, the turbine efficiency change amount is calculated after adding the weight to the gas turbine output change amount in each of the compressor flow rate change amount, the compressor efficiency change amount, and the turbine cooling air amount change amount. In addition, it is possible to grasp the breakdown of the amount of change in gas turbine output. In addition, if the breakdown can be grasped, it is possible to propose specific countermeasures.

The first calculation means in the monitoring device includes a turbine inlet flow rate change amount of the compressed air calculated based on a compressor outlet pressure change amount which is a change amount of the compressor outlet pressure in a predetermined period, and the compressor flow rate. The turbine cooling air amount change amount may be calculated based on the change amount.
As a result, the amount of change in the turbine cooling air can be simply calculated without a flow meter for measuring the amount of change in the cooling air supplied to the turbine or special measurement. Also, the turbine inlet flow rate change amount of compressed air is the flow rate change amount of compressed air introduced into the turbine inlet. In the case of the turbine inlet flow rate, the fuel gas in which the turbine inlet air and the fuel are burned may be indicated, but in the present invention, it has a different meaning and indicates the flow rate of the air containing no fuel.

In the monitoring apparatus, the first calculating means is a compressor inlet that is a flow rate of the intake air on the inlet side of the compressor based on an index differential pressure measured from an index differential pressure gauge attached to the gas turbine intake air. The flow rate and the compressor flow rate change amount may be calculated.
Thereby, the compressor inlet flow rate can be easily calculated.

The monitoring device may further include a deterioration determination unit that determines that the seal in the turbine has deteriorated when the amount of change in the amount of turbine cooling air exceeds a predetermined threshold.
As described above, the deterioration of the predetermined component (seal) in the turbine is determined based on the change amount of the turbine cooling air amount, and information that affects the turbine performance can be easily obtained. Further, since the deteriorated part can be estimated based on the amount of change in the turbine cooling air amount, more specific proposals such as replacement of parts of the deteriorated part estimated for the customer can be made.

  The present invention provides a gas turbine facility including any one of the monitoring devices described above and a gas turbine.

The present invention is a gas turbine monitoring system comprising any one of the above monitoring devices and a gas turbine, wherein the monitoring device is connected to the gas turbine via a network, and the gas turbine is provided. A gas turbine monitoring system provided at a remote location from a specified location is provided.
Even when a gas turbine is installed in a power plant and the monitoring device described above is installed in a management company located in a location remote from the power plant that monitors the state of the gas turbine, Information that can determine the performance of the turbine can be obtained. Thereby, the management company provided with the monitoring device can remotely monitor the gas turbine.

In the present invention, the intake air supplied from the inlet side of the compressor is compressed in the compressor to become compressed air, supplied to the turbine through the combustor, and cooling air for cooling the turbine extracted from the compressor A monitoring method applied to a gas turbine supplied to a turbine, wherein a change in compressor flow rate, which is a change in flow rate of the intake air on the inlet side of the compressor, and a change in efficiency of the compressor in a predetermined period compressor efficiency change amount is an amount, before Symbol turbine cooling air quantity variation is the flow rate variation of the cooling air inlet side of the turbine, and the calculating the gas turbine output change amount which is the amount of change of the gas turbine output a first calculation step, and the compressor flow rate change amount obtained by multiplying the respective weighting factor for the gas turbine output change amount, and the compressor efficiency variation, the turbine cooling air Each of the sum of the amount of change by subtracting from the gas turbine output change amount, provides a monitoring method and a second calculation step of calculating a turbine efficiency change amount.

In the present invention, the intake air supplied from the inlet side of the compressor is compressed in the compressor to become compressed air, supplied to the turbine through the combustor, and cooling air for cooling the turbine extracted from the compressor A monitoring program applied to a gas turbine supplied to a turbine, wherein a change in compressor flow rate, which is a flow rate change amount of the intake air on the inlet side of the compressor, and a change in efficiency of the compressor in a predetermined period compressor efficiency change amount is an amount, before Symbol turbine cooling air quantity variation is the flow rate variation of the cooling air inlet side of the turbine, and the calculating the gas turbine output change amount which is the amount of change of the gas turbine output a first calculation process, and the compressor flow rate change amount obtained by multiplying the respective weighting factor for the gas turbine output change amount, and the compressor efficiency variation, the turbine-cooling Each of the sum of the air quantity variation by subtracting from the gas turbine output change amount, provides a monitoring program for executing a second calculation process for calculating a turbine efficiency change amount to the computer.

  The present invention has an effect that the amount of change in turbine efficiency can be easily calculated without a special measuring instrument.

It is the figure which showed schematic structure of the gas turbine equipment which concerns on the 1st Embodiment of this invention. It is a figure for demonstrating the index differential pressure | voltage which concerns on the 1st Embodiment of this invention. It is the figure which showed schematic structure of the monitoring apparatus which concerns on the 1st Embodiment of this invention. It is a functional block diagram of the monitoring apparatus which concerns on the 1st Embodiment of this invention. It is the figure which showed schematic structure of the gas turbine equipment which concerns on the 2nd Embodiment of this invention. It is the figure which showed an example of the 2nd correspondence information. It is the figure which showed schematic structure of the gas turbine monitoring system which concerns on the 3rd Embodiment of this invention.

DESCRIPTION OF EMBODIMENTS Embodiments of a monitoring apparatus and method, a program, a gas turbine facility including the monitoring apparatus, and a gas turbine monitoring system according to the present invention will be described below with reference to the drawings.
[First Embodiment]
Hereinafter, a first embodiment of the present invention will be described with reference to FIG.
As shown in FIG. 1, the gas turbine equipment 30 according to the present embodiment includes a gas turbine 20 and a monitoring device 10. The gas turbine 20 includes a compressor 1, a combustor 2, a turbine 3, a cooling air pipe 5, a rotating shaft 6, a generator 7, a flow rate measuring unit 8, thermometers (thermocouples) Ta and Tb, pressure gauges Pa and Pb, And an index differential pressure gauge DP.

The downstream side of the compressor 1 is branched into two paths, one connected to the turbine 3 via the combustor 2 and the other by a cooling air pipe 5 which is a path through which cooling air for cooling the turbine 3 flows. The turbine 3 is connected. The turbine 3 is driven by expanding a high-temperature high-pressure gas therein, and is configured to generate electricity by turning a generator 7.
The compressor 1 compresses intake air supplied from the inlet side to generate compressed air, and supplies the compressed air to the combustor 2. The compressor 1 is provided on the rotating shaft 6 together with the turbine 3, and is driven to rotate by the turbine 3. The compressor 1 also extracts cooling air for cooling the turbine 3, distributes the cooling air piping 5, and supplies the cooling air to the turbine 3. In FIG. 1, the cooling air pipe 5 is described as one system extracted from the outlet portion of the compressor 1. However, a system for extracting air from the intermediate stage portion of the compressor 1 may be provided, and is particularly limited. Not.

The turbine 3 extracts the rotational driving force from the combustion gas supplied from the combustor 2 and outputs the driving force. The output rotational driving force is transmitted to the generator 7 connected on the same axis, and the generator 7 generates power, or is transmitted to the compressor 1 connected to the turbine 3 on the same axis. Drive.
The combustor 2 mixes the compressed air supplied from the compressor 1 and the fuel gas, generates high-temperature combustion gas, and supplies it to the turbine 3.

The pressure gauge Pa is provided in the intake air flow path on the inlet side of the compressor 1 and measures the compressor inlet pressure, which is the pressure on the inlet side of the compressor 1.
The pressure gauge Pb is provided in a flow path of compressed air on the outlet side of the compressor 1 and measures a compressor outlet pressure that is a pressure on the outlet side of the compressor 1.
The compressor outlet pressure may be measured as a pressure in a passenger compartment (not shown) in which the combustor 2 is accommodated. Even if the intake air amount of the compressor 1 is the same, if the cooling air amount of the turbine 3 increases, the amount of compressed air introduced into the turbine 3 decreases, and as a result, the outlet pressure of the compressor 1 decreases. That is, by measuring the compressor outlet pressure value, the amount of change in the amount of compressed air introduced into the turbine 3 in a predetermined period can be grasped.

The thermometer Ta is provided in the intake air flow path on the inlet side of the compressor 1 and measures the compressor inlet temperature which is the temperature on the inlet side of the compressor 1.
The thermometer Tb is provided in a flow path of compressed air on the outlet side of the compressor 1 and measures a compressor outlet temperature that is a temperature on the outlet side of the compressor 1.

As shown in FIG. 2, the index differential pressure gauge DP measures the pressure difference between the passage through which the gas turbine intake air flowing into the compressor 1 flows and the inlet side of the compressor 1, and uses the measured value as the index differential pressure. The index differential pressure information is transmitted to the monitoring device 10.
Further, when the index differential pressure increases, the inlet flow rate of the intake air of the compressor 1 increases, and the amount of change (aging) can be grasped by measuring for a predetermined period.
The flow rate measuring unit 8 is provided in the cooling air pipe 5 and measures the flow rate of the cooling air extracted from the compressor 1.

FIG. 3 is a block diagram showing a schematic configuration of the monitoring apparatus 10 according to the present embodiment.
As shown in FIG. 3, the monitoring apparatus 10 according to the present embodiment is a computer system (computer system), a CPU (Central Processing Unit) 101, a main storage device 102 such as a RAM (Random Access Memory), and an auxiliary storage. The apparatus 103 includes an input device 104 such as a keyboard and a mouse, an output device 105 such as a display and a printer, and a communication device 106 that exchanges information by communicating with external devices.
The auxiliary storage device 103 is a computer-readable recording medium, such as a magnetic disk, a magneto-optical disk, a CD-ROM, a DVD-ROM, or a semiconductor memory. Various programs (for example, a monitoring program) are stored in the auxiliary storage device 103, and the CPU 101 reads out the programs from the auxiliary storage device 103 to the main storage device 102 and executes them to implement various processes.

  Next, processing contents executed in each unit included in the monitoring device 10 will be described with reference to FIG. FIG. 4 is a functional block diagram in which the functions of the monitoring device 10 are expanded. As shown in FIG. 4, the monitoring device 10 includes a first calculation unit (first calculation unit) 11, a second calculation unit (second calculation unit) 12, and a deterioration determination unit (degradation determination unit) 13. Yes.

The first calculation unit 11 includes a compressor flow rate change amount Da that is a flow rate change amount of intake air on the inlet side of the compressor 1 and a compressor efficiency change amount Db that is a change amount of efficiency of the compressor 1 during a predetermined period. And a turbine cooling air amount change amount Dc that is a flow amount change amount of the cooling air of the turbine is calculated.
The first calculation unit 11 is based on the index differential pressure measured from the index differential pressure gauge DP attached to the gas turbine intake air, and the compressor inlet flow rate and the compressor flow rate change amount that are the inlet flow rates of the intake air of the compressor 1. Da is calculated. More specifically, the first calculator 11 has first correspondence information (for example, a relational expression) for calculating the inlet flow rate with respect to the index differential pressure when the index differential pressure information is input. The inlet flow rate of the compressor 1 is calculated based on the first correspondence information. Moreover, the 1st calculation part 11 calculates the variation | change_quantity of the compressor inlet flow in the predetermined period as the compressor flow variation | change_quantity Da based on 1st corresponding | compatible information. As described above, the first calculation unit 11 simply calculates the compressor flow rate change amount Da by measuring the index differential pressure with the index differential pressure gauge DP.

Moreover, the 1st calculation part 11 is information on the temperature of the inlet and outlet of the compressor 1 measured from the thermometers Ta and Tb, and the inlet and outlet of the compressor 1 measured from the pressure gauges Pa and Pb in a predetermined period. Based on the outlet pressure information, a compressor efficiency change amount Db, which is a change amount of the efficiency of the compressor 1, is calculated. Further, the first calculation unit 11 obtains a measurement value of the flow rate measured from the flow rate measurement unit 8 for a predetermined period, and calculates the change amount of the cooling air flow rate during the predetermined period as the turbine cooling air amount change amount Dc.
Moreover, the 1st calculation part 11 acquires a gas turbine output value from the output meter etc. of a generator, and calculates it as a gas turbine output change amount in a predetermined period.
Here, the predetermined period is, for example, a time point when the gas turbine 20 is installed and started operation, a time point when parts of the gas turbine 20 are replaced or regularly checked, and the like, and a predetermined interval from the operation reference point. (For example, 2 years).

The second calculator 12 calculates the turbine efficiency change amount Dd based on the compressor flow rate change amount Da, the compressor efficiency change amount Db, and the turbine cooling air amount change amount Dc. That is, by influencing factors affecting the gas turbine output change amount into a compressor flow rate change amount Da, a compressor efficiency change amount Db, a turbine cooling air amount change amount Dc, and a turbine efficiency change amount Dd. The turbine efficiency change amount Dd can be estimated based on the measurable gas turbine output change amount, the compressor flow rate change amount Da, the compressor efficiency change amount Db, and the turbine cooling air change amount Dc.
Specifically, as shown in the following formula (1), the second calculation unit 12 compresses the gas turbine output change amount, which is the change amount of the gas turbine output during a predetermined period, by a weighting coefficient C1. The sum of the machine flow rate change amount Da, the compressor efficiency change amount Db multiplied by the weighting coefficient C2, and the turbine cooling air amount change amount Dc multiplied by the weighting coefficient C3 is subtracted from the gas turbine output change amount. An efficiency change amount Dd is calculated. The turbine efficiency change amount Dd is also multiplied by a weighting coefficient C4 for the gas turbine output change amount.

The weighting coefficients C1 to C4 are coefficients obtained by calculation in advance for design. In the following equation (1), Da is a change in compressor flow rate, Db is a change in compressor efficiency, Dc is a change in turbine cooling air amount, Dd is shown as a turbine efficiency change amount.
Dd × C4 = Gas turbine output change amount− (Da × C1 + Db × C2 + Dc × C3) (1)
The accuracy of the calculation result of the turbine efficiency change amount Dd is best when the gas turbine is fully loaded, but is not limited to this. For example, by changing each of the weighting coefficients C1 to C4, Can also be supported.

  The deterioration determination unit 13 determines that the seal in the turbine has deteriorated when the turbine cooling air amount change amount Dc exceeds a predetermined threshold Th. Moreover, it is preferable that the deterioration determination unit 13 sets the threshold Th by obtaining a correlation between the amount of change in the seal and the amount of change in the flow rate of the cooling air based on design or experiment. In addition, the deterioration determination unit 13 outputs the determination result to the output device 105 or the like, and notifies the operator who operates the monitoring device 10 of the presence or absence of deterioration via the output device 105 or the like.

Next, the processing content performed in each part with which the gas turbine equipment 30 mentioned above is provided is demonstrated with reference to FIGS. Note that various processes described below that are realized by the respective units illustrated in FIG. 4 are realized by the CPU 101 reading out and executing the monitoring program stored in the auxiliary storage device 103 to the main storage device 102.
When the operation of the gas turbine 20 is started, intake air is supplied from the inlet side of the compressor 1 and is compressed by the compressor 1 to become compressed air. When the compressed air is supplied to the combustor 2, it is mixed with fuel gas in the combustor 2, and high-temperature combustion gas is generated and supplied to the turbine 3. In the turbine 3, a rotational driving force is generated from the combustion gas supplied from the combustor 2, and this driving force is output to the generator 7 connected coaxially. On the other hand, the cooling air extracted from the compressor 1 flows through the cooling air pipe 5 and cools the turbine 3.

Thus, the operation of the monitoring device 10 when the operation of the gas turbine 20 is started and the intake air is circulated to the turbine 3 will be described.
When the operation of the gas turbine facility 30 is started and intake air is supplied from the inlet side of the compressor 1, the index differential pressure at the inlet side of the compressor 1 is measured by the index differential pressure gauge DP, and the measured index differential pressure is measured. The measured value is transmitted to the monitoring device 10. The inlet pressure of the intake air compressor 1 is measured by the pressure gauge Pa, and the inlet temperature of the intake air compressor 1 is measured by the thermometer Ta, and each measured value is transmitted to the monitoring device 10.

The compressed air discharged from the compressor 1 is measured by the pressure gauge Pb and the outlet pressure of the compressed air compressor 1 by the thermometer Tb and the outlet temperature of the compressed air compressor 1 by the thermometer Tb. It is transmitted to the monitoring device 10.
When the cooling air extracted from the compressor 1 flows through the cooling air pipe 5 and is supplied to the turbine 3, the flow rate of the cooling air is measured by the flow rate measuring unit 8, and the measured flow rate information is monitored. Transmitted to the device 10.

  The first calculator 11 calculates the inlet flow rate of the intake air of the compressor 1 corresponding to the acquired measured value of the index differential pressure based on the first correspondence information, and calculates the compressor flow rate change amount Da during a predetermined period. Is done. Further, the first calculation unit 11 calculates the compressor efficiency based on the thermometers Ta and Tb and the pressure gauges Pa and Pb, and calculates the compressor efficiency change amount Db in a predetermined period. Further, the first calculation unit 11 calculates a turbine cooling air amount change amount Dc that is the flow rate of the cooling air in the predetermined period of the cooling air acquired from the flow rate measurement unit 8.

In the second calculation unit 12, as shown in the above equation (1), the gas turbine is used for each of the calculated compressor flow rate change amount Da, compressor efficiency change amount Db, and turbine cooling air amount change amount Dc. Weighting coefficients C1, C2, and C3 for the output change amount are added, and the compressor flow rate change amount Da, the compressor efficiency change amount Db, and the turbine cooling, which are obtained by multiplying the respective weighting factors by the gas turbine output change amount. By subtracting the air amount change amount Dc, the turbine efficiency change amount Dd is calculated. At this time, the weighting coefficient C4 for the gas turbine output change amount is also added to the turbine efficiency change amount Dd.
Further, the deterioration determining unit 13 monitors whether or not the turbine cooling air amount change amount Dc exceeds a predetermined threshold Th, and if it exceeds, it is determined that deterioration (wear) has occurred in the seal of the turbine 3. The determination result is output to the output device 105.

  As described above, the operator who operates the monitoring apparatus 10 obtains the turbine efficiency change amount Dd based on the compressor flow rate change amount Da, the compressor efficiency change amount Db, and the turbine cooling air amount change amount Dc. Turbine efficiency can be easily grasped. Further, since each of the change amounts Da to Dd is multiplied by a weighting coefficient for the gas turbine output change amount, the breakdown of the gas turbine output change amount can be grasped. Further, when the occurrence of seal deterioration of the turbine 3 is estimated, the information is displayed on the output device 105, and the operator who has confirmed the output device 105 can easily grasp the deterioration of the performance of the gas turbine. A specific countermeasure (for example, seal replacement etc.) can be proposed to the customer who has 20.

As described above, according to the monitoring device 10 and the method, the program, and the gas turbine facility 30 according to this embodiment, the amount of change in the flow rate of the intake air supplied from the inlet side of the compressor 1 is compressed. Is calculated as the machine flow rate change amount Da, and the compressor efficiency change amount Db is calculated based on the pressure and temperature of the inlet and outlet of the compressor 1 during a predetermined period, and the flow rate measured by the flow rate measuring unit 8 during the predetermined period. A turbine cooling air amount change amount Dc is calculated, and a turbine efficiency change amount Dd is calculated based on the compressor flow rate change amount Da, the compressor efficiency change amount Db, and the turbine cooling air amount change amount Dc.
In this way, the turbine cooling efficiency change amount Dd can be easily calculated without a special measuring instrument. Further, by calculating the turbine efficiency change amount Dd in this manner, the state of the gap (tip clearance) between the rotor blade tip (tip) and the stationary blade of the turbine, the wear of the turbine (including melting), the deposit ( It can be understood that there is a possibility that a problem may occur in the point that causes reduction in turbine efficiency such as accumulation of foreign matter), increase in exhaust-side pressure loss, damage to the diffuser, and the like.

  Further, each of the compressor flow rate change amount Da, the compressor efficiency change amount Db, the turbine cooling air amount change amount Dc, and the turbine efficiency change amount Dd is multiplied by a weighting coefficient for the gas turbine output change amount to change the turbine efficiency change. Since the amount Dd is calculated, it is possible to accurately grasp the breakdown of the amount of change in gas turbine output, and it is possible to propose specific countermeasures based on the breakdown.

  In the present embodiment, the measurement value measured by the index differential pressure gauge DP has been described as being output to the monitoring device 10 by the index differential pressure gauge DP. However, the present invention is not limited to this. For example, the monitoring device 10 obtains a measurement value of the index differential pressure by starting communication such as acquiring information of the measurement value of the index differential pressure from the monitoring device 10 side to the index differential pressure gauge DP. It is good.

[Second Embodiment]
Next, a monitoring apparatus according to a second embodiment of the present invention will be described with reference to FIG. The monitoring device of the present embodiment is different from the first embodiment in that the first calculation unit calculates the amount of change in turbine cooling air based on the compressor outlet pressure. Hereinafter, regarding the gas turbine facility 30 ′ of the present embodiment, description of points that are common to the first embodiment will be omitted, and different points will be mainly described.

The first calculation unit is based on the turbine inlet flow rate change amount Dt of the compressed air and the compressor flow rate change amount Da calculated based on the compressor outlet pressure change amount which is the change amount of the compressor outlet pressure in a predetermined period. Then, a turbine cooling air amount change amount Dc is calculated. Specifically, the first calculation unit includes second correspondence information (for example, a relational expression) for calculating the turbine inlet flow rate change amount of the compressed air with respect to the change amount of the compressor outlet pressure. When the information on the compressor outlet pressure measured by the pressure gauge Pb is input to the first calculator, the change in the turbine inlet flow rate of the compressed air with respect to the amount of change in the compressor outlet pressure during a predetermined period based on the second correspondence information While calculating the amount Dt, the turbine cooling air amount change amount Dc is calculated by subtracting the turbine inlet flow rate change amount Dt of compressed air from the compressor flow rate change amount Da as shown in the following equation (2).
Turbine cooling air amount change amount Dc = Compressor flow rate change amount Da-turbine inlet flow rate change amount Dt (2)

  For example, the second correspondence information is a function (graph) showing a correlation between the compressor outlet pressure and the turbine inlet flow rate, as shown in FIG. When the compressor outlet pressure is reduced, the turbine inlet flow rate is decreased, and when the compressor outlet pressure is increased, the turbine inlet flow rate is increased. Here, the “turbine inlet flow rate change amount Dt of compressed air” is the flow rate change amount of compressed air introduced into the turbine inlet. The turbine inlet flow rate may indicate combustion gas obtained by burning the turbine inlet air and the fuel, but in the present invention, it has a different meaning and indicates the flow rate of air not containing fuel.

  Thus, since the turbine cooling air amount change amount Dc is calculated based on the turbine inlet flow rate change amount Dt and the compressor flow rate change amount Da of the compressed air calculated based on the compressor outlet pressure, the cooling air It is not necessary to provide the flow rate measuring unit 8 in the pipe 5, so that the cost can be reduced and the turbine cooling air amount change amount Dc can be calculated easily.

[Third Embodiment]
Next, a monitoring device according to a third embodiment of the present invention will be described with reference to FIG. The monitoring device of the present embodiment is different from the first embodiment in that the gas turbine 20 and the monitoring device 10 are connected via a network 9, and the monitoring device 10 is remote from the position where the gas turbine 20 is provided. The gas turbine monitoring system 40 is provided on the ground. Hereinafter, regarding the gas turbine monitoring system 40 of the present embodiment, description of points that are common to the first embodiment and the second embodiment is omitted, and different points are mainly described.

In the present embodiment, as shown in FIG. 7, a gas turbine 20 is provided in the power plant, and a monitoring device 10 is provided in a monitoring room of a management company located remotely from the power plant via the network 9. .
The network 9 is a network using a standardized communication protocol (for example, TCP / IP) for gas turbine management, and may be a LAN (Local Area Network), an optical line or a VPN (Virtual Private Network). It may be a WAN (Wide Area Network) using a public line such as Network) or a dedicated line, and is not particularly limited.

The index differential pressure gauge DP outputs information on the measured value of the index differential pressure to the monitoring device 10 via the network 9.
The pressure gauge Pb outputs information on the measured value of the compressor outlet pressure to the monitoring device 10 via the network 9.
The monitoring device 10 calculates the compressor flow rate change amount Da based on the measured value of the index differential pressure acquired from the index differential pressure gauge DP, and the measured value (vehicle compartment pressure value) of the compressor outlet pressure acquired from the pressure gauge Pb. Based on the above, the turbine inlet flow rate change amount Dt is calculated.

  The first calculating unit is configured to change the compressor flow rate Da during a predetermined period based on the measured value of the index differential pressure output from the index differential pressure gauge DP provided in the gas turbine 20 in the power plant remote from the monitoring device 10. Is calculated. In addition, the first calculation unit includes information on the inlet and outlet temperatures of the compressor acquired from the thermometers Ta and Tb provided in the gas turbine 20 in the power plant remote from the monitoring device 10, and the pressure gauges Pa and Pb. The compressor efficiency change amount Db for a predetermined period is calculated based on the information on the pressure at the inlet and the outlet of the compressor acquired from the above.

Furthermore, the first calculation unit calculates the turbine inlet flow rate change amount Dt based on the compressor outlet pressure value output from the pressure gauge Pb provided in the gas turbine 20 in the power plant remote from the monitoring device 10. Based on the compressor flow rate change amount Da and the turbine inlet flow rate change amount Dt, the turbine cooling air amount change amount Dc is calculated.
The second calculation unit calculates the turbine efficiency change amount Dd based on the compressor flow rate change amount Da, the compressor efficiency change amount Db, and the turbine cooling air amount change amount Dc.
The deterioration determination unit monitors whether or not the turbine cooling air amount Dc exceeds a predetermined threshold Th, and if it exceeds, determines that deterioration (wear) has occurred in the turbine seal, and determines the determination result. Output to an output device.

  As described above, according to the gas turbine monitoring system 40 of the present invention, the gas turbine 20 is provided in the power plant, and the monitoring device 10 is provided in a management company in a location remote from the power plant. Even when the gas turbine 20 and the monitoring device 10 are remotely arranged, information for determining the performance of the gas turbine 20 can be obtained from the management company having the monitoring device 10 via the network 9. As a result, the operator can remotely monitor the gas turbine 20 provided in the power plant remote from the management company while being in the management company. In addition, when wear of a predetermined location such as seal deterioration has occurred, deterioration information and the like can be obtained, so specific proposals such as seal replacement can be made to the customer who has the gas turbine 20 while remotely. It can be carried out.

DESCRIPTION OF SYMBOLS 1 Compressor 2 Combustor 3 Turbine 5 Cooling air piping 8 Flow rate measurement part 10 Monitoring apparatus 11 1st calculation part (1st calculation means)
12 2nd calculation part (2nd calculation means)
13 Degradation determination unit (degradation determination means)
20 Gas turbine 30 Gas turbine equipment 40 Gas turbine monitoring system DP Index differential pressure gauge Pa, Pb Pressure gauge Ta, Tb Thermometer

Claims (8)

Intake air supplied from the inlet side of the compressor is compressed in the compressor to become compressed air, supplied to the turbine via the combustor, and cooling air for cooling the turbine extracted from the compressor is supplied to the turbine. A monitoring device applied to a gas turbine,
During a predetermined period, the compressor flow rate variation is a change in the flow rate of the intake air inlet side of the compressor, the amount of change in the efficiency of the compressor efficiency change amount of the compressor, the prior SL inlet side of the turbine First calculation means for calculating a turbine cooling air amount change amount that is a flow amount change amount of cooling air and a gas turbine output change amount that is a change amount of the gas turbine output ;
The sum of the compressor flow rate change amount, the compressor efficiency change amount, and the turbine cooling air amount change amount obtained by multiplying the respective weighting coefficients for the gas turbine output change amount is the gas turbine output change amount. And a second calculating means for calculating a turbine efficiency change amount by subtracting from the monitoring device. The first calculating means includes a turbine inlet flow rate change amount of the compressed air calculated based on a compressor outlet pressure change amount, which is a change amount of the compressor outlet pressure during a predetermined period, and a compressor flow rate change amount. based on the monitoring device according to claim 1 for calculating the turbine cooling air quantity change amount. The first calculation means includes a compressor inlet flow rate, which is a flow rate of the intake air on the inlet side of the compressor, and the compressor based on an index differential pressure measured from an index differential pressure gauge attached to the gas turbine intake air. monitoring device according to claim 1 or claim 2 for calculating the flow rate variation. The monitoring apparatus according to any one of claims 1 to 3 , further comprising a deterioration determination unit that determines that the seal in the turbine has deteriorated when the amount of change in the amount of turbine cooling air exceeds a predetermined threshold value. A gas turbine equipment comprising the monitoring device according to any one of claims 1 to 4 and a gas turbine. A gas turbine monitoring system comprising the monitoring device according to any one of claims 1 to 4 and a gas turbine,
The said monitoring apparatus is connected with the said gas turbine via a network, The gas turbine monitoring system with which a remote place is equipped from the position in which the said gas turbine is provided. Intake air supplied from the inlet side of the compressor is compressed in the compressor to become compressed air, supplied to the turbine via the combustor, and cooling air for cooling the turbine extracted from the compressor is supplied to the turbine. A monitoring method applied to a gas turbine comprising:
During a predetermined period, the compressor flow rate variation is a change in the flow rate of the intake air inlet side of the compressor, the amount of change in the efficiency of the compressor efficiency change amount of the compressor, the prior SL inlet side of the turbine A first calculation step of calculating a turbine cooling air amount change amount that is a flow rate change amount of the cooling air and a gas turbine output change amount that is a change amount of the gas turbine output ;
The sum of the compressor flow rate change amount, the compressor efficiency change amount, and the turbine cooling air amount change amount obtained by multiplying the respective weighting coefficients for the gas turbine output change amount is the gas turbine output change amount. And a second calculation step of calculating a turbine efficiency change amount by subtracting from the second method. Intake air supplied from the inlet side of the compressor is compressed in the compressor to become compressed air, supplied to the turbine via the combustor, and cooling air for cooling the turbine extracted from the compressor is supplied to the turbine. A monitoring program applied to a gas turbine,
During a predetermined period, the compressor flow rate variation is a change in the flow rate of the intake air inlet side of the compressor, the amount of change in the efficiency of the compressor efficiency change amount of the compressor, the prior SL inlet side of the turbine A first calculation process for calculating a turbine cooling air amount change amount that is a flow rate change amount of the cooling air and a gas turbine output change amount that is a change amount of the gas turbine output ;
The sum of the compressor flow rate change amount, the compressor efficiency change amount, and the turbine cooling air amount change amount obtained by multiplying the respective weighting coefficients for the gas turbine output change amount is the gas turbine output change amount. A monitoring program for causing a computer to execute a second calculation process for subtracting from the second calculation process to calculate a turbine efficiency change amount.

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