JP2013148367A - Smart radiation thermometry system for real-time gas turbine control and prediction - Google Patents

Abstract

PROBLEM TO BE SOLVED: To perform real-time gas turbine control and prediction in a smart radiation thermometry system.SOLUTION: A smart radiation thermometry system including a turbine component 18 is provided. The smart radiation thermometry system includes an optical imaging sub-system configured to receive a continuous broad wavelength band radiation signal emitted by the turbine component 18. The thermometry system also includes a wavelength splitting sub-system which is in optical communication with the optical transmission sub-system, receives the continuous broad wavelength band radiation signal, and splits the radiation signal into multiple sub-wavelength band signals. The thermometry system further includes at least one detector array 42 which is in optical communication with the wavelength-splitting sub-system, receives the multiple sub-wavelength band signals, and outputs respective analog voltage signals for the respective signals.

Description

  The present invention relates generally to smart radiation temperature measurement systems, and more particularly to a multi-wavelength radiation temperature measurement system for real-time gas turbine control and prediction.

  It is well known that the efficiency of a gas turbine can be increased by raising the operating temperature of the turbine. An increase in operating temperature adversely affects gas turbine reliability, availability, and radiation. Increasing operating temperatures can exceed the thermal limits of certain engine components, particularly high temperature (HGP) components such as turbine blades and nozzles, resulting in reduced service life or even material failure. In addition, the thermal expansion and contraction of the parts also affects the clearance and interfitting relations with other parts. Therefore, it is desirable to monitor the temperature of the turbine component during operation of the gas turbine to ensure that the turbine component does not exceed the maximum rated temperature for an appropriate period of time. For example, HGP component temperature information is used in a gas turbine controller to adapt the actuator to adjust the maximum working temperature by changing fuel flow, vane angle, nozzle area, etc. be able to. In addition, measured temperatures and trends can be used to predict the remaining life of expensive gas turbine components and estimate the associated risks.

  A common approach to monitoring the temperature of turbine HGP components is to indirectly measure the temperature of the gas exiting the turbine and use this as an indicator of blade temperature. Turbine outlet temperature can be measured by installing one or more temperature sensors, such as thermocouples, in the exhaust stream. Since the blade temperature is measured indirectly, it is relatively inaccurate. Therefore, since it is necessary to maintain a wide safety range, the optimum temperature cannot be used.

  The disadvantages of indirect temperature measurement of HGP parts are well known and techniques for directly measuring the temperature of HGP parts have been proposed. One direct measurement approach uses a single detection wavelength range radiation pyrometer that is external to the engine casing and has a field of view focused on the turbine blades through a viewing window formed in the casing wall. Thus, the radiation emitted by the heated turbine HGP component strikes the pyrometer, which in turn generates an electrical signal representative of the temperature of the HGP component. However, the viewing window is exposed to hot exhaust gases that tend to cloud the viewing window and adversely affect temperature readings during engine operation. Furthermore, significant improvements are needed in the time response of the thermal inspection system that changes the fuel ratio and the processing time for calculating temperature and emissivity.

US Pat. No. 7,690,840

  Accordingly, it would be desirable to have an improved smart real-time radiation temperature measurement system that addresses one or more of the aforementioned problems.

  According to one embodiment of the present invention, a smart radiation temperature measurement system is provided that includes a turbine HGP component. The smart radiation thermometry system includes an optical imaging subsystem that is configured to receive a continuous wide wavelength radiation signal emitted by an HGP component. The temperature measurement system also includes a wavelength division subsystem that is in optical communication with the optical transmission system and that receives a continuous wide wavelength band radiation signal and divides the radiation signal into a plurality of sub wavelength band signals. The temperature measurement system is at least one detector array in optical communication with a wavelength division subsystem, receiving at least one sub-wavelength signal and outputting a respective analog voltage signal for each of the signals. Further comprising a vessel array. The temperature measurement system is at least one high-speed multi-channel analog-to-digital converter (ADC) electrically coupled to at least one detector array, digitizing each analog voltage signal and converting the digital voltage signal to It further includes at least one ADC to output. The temperature measurement system also includes at least one smart real-time processing subsystem that is electrically coupled to the at least one high-speed multi-channel ADC. This smart real-time processing subsystem uses the digital voltage signal from at least one high-speed multi-channel ADC to calculate the temperature and emissivity of the turbine HGP component based on reflection correction and a multi-wavelength algorithm. The at least one smart real-time processing subsystem also sends data indicative of temperature, emissivity, and other parameters within a predetermined time period using the built-in communication unit. The at least one smart real-time processing subsystem also outputs an emergency alert signal and directs one or more actuators coupled to the gas turbine based on the data to ensure optimal and safe operation. Or via the control device.

  According to another embodiment of the present invention, a method for thermal measurement of a turbine HGP component is provided. The method includes receiving a continuous wide wavelength radiation signal emitted by a turbine HGP component via an optical imaging subsystem. The method also includes receiving the radiation signal via a wavelength division subsystem and dividing the continuous wide wavelength radiation signal of the turbine component into a plurality of sub-wavelength signals. The method also includes receiving a plurality of wavelength band signals via at least one detector array and outputting a respective analog voltage signal for each of the sub-wavelength signals. The method further includes digitizing each analog voltage signal and outputting a digital voltage signal via at least one high-speed multi-channel ADC. The method also includes performing a plurality of processing steps using at least one smart real-time processing subsystem using the digital signal. These steps include checking and compensating the digital voltage signal, calculating a radiance temperature from a look-up table, a turbine based on this radiance temperature, reflection correction, and a multi-wavelength algorithm. Calculating the temperature and emissivity of the component and sending data indicative of temperature, emissivity, and other parameters to the internal communication unit within a predetermined period of time. These steps are based on the data to output an emergency alert signal to directly or one or more actuators coupled to the gas turbine to ensure optimal and safe operation of the turbine. Via the control step.

  According to another embodiment of the present invention, a temperature measurement processing system for a turbine HGP component is provided. The temperature measurement processing system includes at least one smart real-time processing subsystem that is electrically coupled to at least one detector array. The at least one smart real-time processing subsystem receives a digital voltage signal representing each of the plurality of sub-wavelength signals from the component. The at least one smart real-time processing subsystem inspects and compensates for the digital voltage signal and calculates the radiance temperature from a look-up table. The at least one smart real-time processing subsystem also calculates the temperature and emissivity of the turbine component based on radiance temperature, reflection correction, and a multi-wavelength algorithm. The at least one smart real-time processing subsystem also sends data indicative of temperature, emissivity, and other parameters to the controller within a predetermined time period. The at least one smart real-time processing subsystem also outputs an emergency alert signal based on the data and includes one or more actuators coupled to the gas turbine to ensure optimal and safe operation of the turbine. Control directly or via a controller.

  The above and other features, aspects and advantages of the present invention will be better understood by reading the following detailed description with reference to the accompanying drawings. Like reference numerals represent like parts throughout the drawings.

1 is a schematic diagram of a turbine system including a smart real-time processing subsystem according to an embodiment of the present invention. FIG. 2 is a simplified block diagram representation of a smart real-time radiation temperature measurement system within the gas turbine system of FIG. FIG. 3 is a block diagram representation of software data processing performed within the smart real-time processing subsystem of FIGS. 1 and 2. FIG. 3 is a block diagram representation of further transmission of output data of the smart real-time processing subsystem of FIGS. 1 and 2. FIG. 3 is a block diagram representation of hardware within the smart real-time processing subsystem of FIGS. 1 and 2. FIG. 6 is a graphical diagram simulating spectral emissivity as a function of wavelength to determine an acceptable operating wavelength according to one embodiment of the present invention. 6 is a block diagram representation of an exemplary embodiment in which a real-time processing subsystem functions as an independent controller, according to one embodiment of the present invention. FIG. 6 is a block diagram representation of another exemplary embodiment in which the real-time processing subsystem generates an alarm signal. FIG. 6 is a block diagram representation of yet another exemplary embodiment in which a real-time processing subsystem sends signals to the turbine controller of FIG. 2 is a flow chart representing steps of an exemplary method for measuring radiation temperature of a turbine HGP component for real-time control and prediction according to an embodiment of the present invention.

  As described in detail below, embodiments of the present invention include systems and methods for thermal inspection of objects. As used herein, the term “object” refers to, but is not limited to, turbine HGP components such as blades and nozzles. The system includes a smart radiation temperature measurement system that provides real-time gas turbine control and prediction with a predetermined, eg, less than about 10 microsecond time response, for example, for fuel injection into a combustor within the gas turbine system. Adjustment is possible. Although the embodiments disclosed herein are described with respect to a gas turbine system, it will be understood that such a smart real-time processing subsystem may be used in a variety of similar applications. Furthermore, although one smart real-time processing subsystem is shown herein, any number of such smart processing subsystems can be used.

  Referring now to the drawings, FIG. 1 is a schematic diagram of a turbine system 10 that includes a smart real-time processing subsystem. This smart real-time processing subsystem estimates the temperature and emissivity of turbine components, such as the blades of the compressor 22, and in real time moves one or more actuators 11 coupled to the turbine system 10 to ensure safe operation. Configured to control. The turbine system 10 includes a fuel injector 12, a fuel supply 14, and a combustor 16. As shown, the fuel supply 14 delivers liquid and / or gaseous fuel, such as natural gas, to the gas turbine system 10 and through the fuel injector 12 to the combustor 16. The fuel injector 12 is configured to inject fuel and mix it with compressed air. The combustor 16 ignites and burns the fuel-air mixture and then passes hot pressurized exhaust gas through the turbine 18. As will be appreciated, the turbine 18 includes one or more stators having stationary vanes or blades and one or more rotors having blades that rotate relative to the stator. The exhaust gas passes through the turbine rotor blades, thereby driving the turbine rotor in rotation. When the turbine rotor and the shaft 19 are coupled, the shaft 19 rotates. The shaft 19 is also coupled to several parts throughout the gas turbine system 10 as shown. Finally, the combustion process exhaust can exit the gas turbine system 10 via the exhaust outlet 20.

  The compressor 22 includes blades rigidly attached to the rotor, and the rotor is driven to rotate by the shaft 19. As air passes through the rotating blades, the air pressure increases, thereby providing the combustor 16 with sufficient air for proper combustion. The compressor 22 can take air into the gas turbine system 10 via the air intake 24. Further, the shaft 19 may be coupled to a load 26 that can be powered by rotation of the shaft 19. As will be appreciated, the load 26 may be any suitable device that can use the power of the rotational output of the gas turbine system 10 such as a power generation plant or an external mechanical load. For example, the load 26 may be a generator, an aircraft propeller, or the like. The air intake 24 draws air 30 into the gas turbine system 10 via a suitable mechanism such as a cold air intake. Air 30 then flows through the blades of compressor 22, which provides compressed air 32 to combustor 16. Specifically, the fuel injector 12 can inject compressed air 32 and fuel 14 into the combustor 16 as a fuel-air mixture 34. Alternatively, compressed air 32 and fuel 14 can be injected directly into the combustor for mixing and combustion.

  As shown, the turbine system 10 includes an optical imaging subsystem 36 that is optically coupled to the turbine 18. In the illustrated embodiment, the optical imaging system 36 includes an optical connection 38 (eg, an optical borescope, extending between a viewing port 39 to the turbine 18 and a wavelength division subsystem 40. Optical fiber cable, optical waveguide, etc.). As will be described in detail below, the wavelength division subsystem 40 is configured to receive a continuous wide wavelength range radiation signal from the turbine HGP component and to divide the wide wavelength range image into a plurality of sub wavelength range signals 41. At least one detector array 42 optically coupled to the wavelength division subsystem 40 is configured to receive each of the sub-wavelength signals and output a respective analog voltage signal 43. In the illustrated embodiment, the detector array 42 is electrically coupled to at least one high-speed multi-channel analog-to-digital converter (ADC) 44 that digitizes the analog signal 43 and outputs a digital signal 45. A smart real-time processing subsystem 46 electrically coupled to at least one high speed multi-channel ADC 44 receives the digital signal 45. The smart real-time processing subsystem 46 inspects and compensates for the digital voltage signal 45 and calculates the radiance temperature using a look-up table. Based on this radiance temperature, reflection correction, and multi-wavelength algorithm, the temperature and emissivity of the turbine component 22 are calculated. Data 53 indicative of temperature and emissivity and other parameters is sent to the controller within a predetermined period of time, for example, less than about 10 microseconds in certain embodiments. In one embodiment, the plurality of parameters include signal / sensor health, signal confidence level, signal selection index, weighting factor, temperature trend log file, temperature statistics, and the like. If the data exceeds the safe operating limits of the turbine system 10, a communication unit (not shown) within the smart real-time processing subsystem 46 outputs an emergency alert. In another embodiment, the smart real-time processing subsystem 46 controls one or more actuators 11 coupled to the turbine system 10 either directly or via the controller 54 based on the data 53. For example, the actuator 11 can adjust the fuel injected into the combustor 16 based on the calculated temperature. In another embodiment, the actuator can adjust the air flow to the compressor 22 based on the calculated data 53.

  FIG. 2 is a simplified block diagram representation of a smart real-time radiation temperature measurement system 60 in a gas turbine system similar to FIG. The optical system 36 (FIG. 1) further includes an optical imaging subsystem 62 and an optical transmission subsystem 64 that send a continuous wide wavelength radiation signal 68 to the wavelength division subsystem 40 (FIG. 1). Optical imaging subsystem 62 receives radiation 65 emitted by gas turbine HGP components, such as turbine blades 66, and sends radiation 65 to optical transmission subsystem 64.

  The optical transmission subsystem 64 sends a continuous wide wavelength radiation signal 68 to the wavelength division subsystem 40, which can include a series of lenses, prisms, mirrors, and optical fibers. The wavelength division subsystem 40 includes a series of lenses, prisms, mirrors, spectrometers, and / or other reflective optical components and / or to divide the continuous wide wavelength radiation signal 68 into a plurality of sub-wavelength signals 72. Alternatively, refractive optical components can be included. As will be appreciated, each of the plurality of sub-wavelength signals 72 includes spectral components (eg, a range of wavelengths) that are substantially similar to the continuous wide-wavelength radiation signal 68. Further, the resolution and field of view of each signal 72 is substantially similar to the continuous wide wavelength region signal 68. However, it should be understood that the intensity of each signal 72 may be inversely proportional to the number of signals 72 generated by the wavelength division subsystem 40. For example, the wavelength division subsystem 40 of the illustrated embodiment generates four sub-wavelength signals 72 so that the intensity of each signal 72 can be approximately 25% of the intensity of the continuous wide-wavelength signal 68. In alternative embodiments, more or fewer sub-wavelength signals (eg, 2, 3, 4, 5, 6, 7, 8, or more) can be generated, but the maximum of sub-wavelength signals It should be understood that the number can be limited by the sensitivity of the detector array 92 that receives multiple sub-wavelength signals 72.

  The detector array 92 outputs a respective analog voltage signal 96 to at least one high-speed multi-channel ADC 98, and the high-speed multi-channel ADC 98 digitizes the signal 96 and outputs it as a digital signal 99. A keyphasor or external trigger unit 97 can also be input to the high speed multi-channel ADC 98. The keyphasor and external trigger unit 97 can be used to synchronize at least one high speed multi-channel ADC with a common time reference. The keyphaser and external trigger unit 97 can also be used to phase lock certain HGP components, particularly for rotating components such as turbine blades. Digital signal 99 is input to smart real-time processing subsystem 102 (similar to 46 in FIG. 1). As described in FIG. 1, the smart real-time processing subsystem 102 processes the digital signal 99 and outputs the temperature and emissivity of the turbine HGP component 66. Data 104 is smart for further adjusting component parameters and thus controlling actuator 108 directly or indirectly through controller 106 to ensure optimal operation of gas turbine 110 within safe operating limits. Sent by a built-in communication unit (not shown) within the real-time processing subsystem 102.

  It should be noted that embodiments of the present invention are not limited to any particular processing apparatus for performing the processing operations of the present invention. As used herein, the term “processing subsystem” is intended to mean any machine capable of performing the calculations or calculations necessary to perform the operations of the present invention. The term “processing subsystem” is intended to mean any machine that can accept structured input, process the input according to predefined rules, and generate output. As will be appreciated by those skilled in the art, the phrase “configured to” as used herein means that the processing unit is equipped with a combination of hardware and software for performing the operations of the present invention. Also note that it means.

  FIG. 3 is a block diagram representation of software data processing performed within the smart real-time processing subsystem 102 (FIG. 2). Raw digital signal data 112 from at least one high-speed multi-channel ADC (98) (FIG. 2) is fed to the real-time processing subsystem 102 and subjected to various standard pre-processing techniques to improve the accuracy of the data. It is done. In a particular flow, various correction models are implemented to ensure real-time processing of the data. The unprocessed signal 112 is input to a background correction module 116 that corrects the dark or background signal. The background-corrected data 118 is input to the non-uniformity correction or gain correction module 120, and the non-uniformity correction or gain correction data 122 is further input to the defective signal replacement module 124. The data output 126 from the bad signal replacement module 124 is input to the calibration module 132 where a reference table “Voltage” vs. “Temperature” stored in the smart real-time processing subsystem to determine the radiance temperature 136. Calibration is performed by Data 136 indicating the radiance temperature is input to the embedded multi-wavelength algorithm 138 along with the correction coefficient from the reflection correction module 142. Radiation from the component of interest (66, FIG. 2) collected by the optical imaging system (62, 64, FIG. 2) is emitted in two parts: the radiation emitted from the blade, and the shroud, nozzle, etc. It may include radiation reflected from adjacent components, including but not limited to. Thus, reflection correction is performed to eliminate components that are reflected from the collected radiation. The reflection corrected data 146 is further processed via a multi-wavelength algorithm 138 to output the raw temperature and emissivity data 152 of the part. To increase processing speed, it may be necessary to run the algorithm in a parallel processing mode.

  In addition, raw temperature and emissivity data 152 is input to a smart signal processing algorithm 156. Smart signal processing algorithm 156 includes low level processing 158, high level processing 162, signal conditioning 164, statistical and trend analysis 166, and control function 168. Low level processing 158 obtains and evaluates the tone of at least one high speed multi-channel ADC 174, while high level processing 162 removes noise or undesired signal 178 (eg, flame or particle signals). Reject), compare signals, blend or discard signals, calculate a quality index for the signal, and calculate status flags that indicate the health of the system, such as bad detectors and bad ADCs. Similarly, signal conditioning 164 implements thermal effect filtering and compensation 182. The filtering function can output a filtered signal at various data rates to match the performance of the controller or actuator. The statistical information and trend analysis 166 outputs a log trend 186 for each part. The control function module 168 outputs control parameters for controlling one or more actuators coupled to the gas turbine, either directly or via a controller.

  FIG. 4 is a block diagram representation of further transmission of output data 202 of smart real-time processing subsystem 102 (FIG. 2). Data 202 is supplied to a built-in communication unit 52 within the smart real-time processing subsystem 102. The communication unit 52 includes three interfaces. One is a digital data interface. One is an analog data interface and the data is further sent to the controller 106 (FIG. 2) or one or more actuators 108 (FIG. 2). The other is a control interface that can read, write, and update data in memory. Calibration data or embedded software can be updated, and trend file log data can be downloaded via the control interface. Further, digital data interfaces include, but are not limited to, Firewire (IEEE 1394), Ethernet (trademark), Gigabit Ethernet (trademark), USB, RS232, and camera link. The analog data interface can output data in the voltage, current, and frequency ranges required by the controller or actuator. Examples of the control interface include, but are not limited to, Firewire (IEEE 1394), Ethernet (trademark), Gigabit Ethernet (trademark), USB, RS232, and camera link.

  FIG. 5 is a block diagram representation of the hardware inside the smart real-time processing subsystem 102 (FIG. 2) or 46 (FIG. 1). Output 99 from at least one high speed ADC 98 (FIG. 2) is input to the smart real-time processing subsystem 102 via an input / output (I / O) interface 106. A field programmable gate array (FPGA) unit 212 is incorporated that is electrically coupled to the I / O interface 106. Further, the digital signal processing (DSP) unit 214 receives the input signal 216 from the FPGA unit 212 and stores the data in the memory 224. The communication unit 228 exchanges the data 232 with the FPGA 212, the DSP 214, and the memory 224, and outputs a signal 232 (FIG. 1). The embedded data processing algorithm is implemented in the FPGA unit 212 or the DSP unit 214. To increase real-time data processing speed, the algorithm is implemented in parallel mode in the FPGA unit 212 or DSP unit 214. Calibration data is stored in memory 224. The results of low level processing 158, high level processing 162, signal conditioning 164, statistical information and trend analysis 166, and control function 168 are also stored in memory. The communication unit 228 can access the memory 224 and output the necessary digital or analog data to the gas turbine controller 106 (FIG. 2) or directly to the actuator.

FIG. 6 is a graph 250 simulating spectral emissivity as a function of wavelength. The X axis 252 represents the wavelength in microns, and the Y axis 254 represents the normalized, and thus dimensionless, spectral emissivity. In operation, radiation emitted by objects such as but not limited to turbine blades can be minimized by absorption by radiation of other gas mixtures such as H ₂ O and CO ₂ , and thus a measurement of the signal to noise ratio. Becomes lower. Graph 250 shows an acceptable operating wavelength range. Here, the emission of such a gas mixture is minimal, and therefore the probability of obtaining a measurement with a high signal-to-noise ratio is maximized. As shown herein, curve 256 represents the emissivity of a mixture of H ₂ O and CO ₂ as a function of wavelength. Similarly, curve 262 represents the actual radiation of the object and curve 264 represents the hot gas radiation. Therefore, the acceptable operating wavelength range (H ₂ O and CO ₂ emissions are negligible) is labeled 0.5-1.1 μm, 1.2-1.3 μm, 1. It can be estimated to be 5-1.7 μm, 2.0-2.4 μm, and 3.5-4.2 μm.

  7-9 are block diagram representations of an exemplary alternative embodiment of the functionality of the smart real-time processing subsystem 102. For example, FIG. 7 illustrates one embodiment where the real-time processing subsystem 102 (FIG. 2) directly adjusts the actuator 108 (FIG. 2) without the controller 106 (FIG. 2). In other words, the real-time processing subsystem functions as an independent control device. Specifically, signal 96 (FIG. 2) from detector array 92 is processed by real-time processing subsystem 102. However, instead of sending the output signal 104 (FIG. 2) to the controller 106, the real-time processing subsystem 102 directly adjusts the actuator 108 (FIG. 2).

  FIG. 8 is a block diagram representation of additional functions of the real-time processing subsystem 102. The real-time processing subsystem 102 generates an alarm signal (s) 282 based on the output signal 104 (FIG. 2) when the temperature / emissivity value exceeds a predetermined limit of operation. Furthermore, the engine can be stopped based on the generated alarm signal. Thus, the real-time processing subsystem can function as an emergency device.

  FIG. 9 is a block diagram representation of an exemplary embodiment in which the real-time processing subsystem 102 sends an output signal 104 to the controller 106 (FIG. 2), which further controls the actuator 108. In certain embodiments, the controller 106 is a general digital engine controller (FADEC). In one such embodiment, the controller makes a decision regarding further operations based on the output signal 104. In other words, the real-time processing subsystem 102 can function as a smart sensor of an existing control device. In one embodiment, a keyphasor or external trigger 97 (FIG. 2) can also be applied to the smart real-time processing subsystem 102. A keyphasor or external trigger 97 can be used to synchronize at least one high-speed multi-channel ADC with the gas turbine's ambient reference and identify specific parts of the gas turbine. This function is particularly important when the object is a fast moving object such as a gas turbine blade. A keyphasor or external trigger 97 can also be used to synchronize the smart real-time radiation thermometry system with other equipment.

  FIG. 10 is a flow diagram representing the steps of an exemplary method for thermal measurement of turbine components. The method includes receiving, at step 302, a continuous wide wavelength radiation signal emitted by a turbine component via an optical imaging subsystem. In step 304, this radiation signal is sent and split into a plurality of sub-wavelength region signals through the wavelength division subsystem. In step 306, the plurality of sub-wavelength signals are received by the at least one detector array and respective analog voltage signals are output. In step 308, the respective voltage signals are digitized and a digital voltage signal is output. In step 312, the digital signal is received by the smart real-time processing subsystem and processed in multiple steps including checking and compensating the digital voltage signal. In step 314, the radiance temperature is calculated from the reference table. In step 316, the temperature and emissivity of the turbine component is calculated based on the radiance temperature, reflection correction, and multiwavelength signal. In step 318, data indicative of temperature, emissivity and other parameters is sent to the communication unit within a predetermined period of time, for example, less than about 10 microseconds. In one embodiment, at step 322, an emergency alert signal is output to shut down the turbine system in order to operate within safety limits. In another embodiment, one or more actuators are controlled directly or indirectly (via a controller) based on the received data to ensure safe operation of the turbine.

  Accordingly, the various embodiments of the smart temperature measurement system described above provide a way to implement a simple and efficient means for real-time measurement of the temperature of an object, such as but not limited to a turbine blade. This technique significantly improves the time response of the system and allows desirable adjustment of fuel injection, among other parameters. Furthermore, the system can be implemented as an independent controller, an emergency device, and a smart sensor of an existing control system, depending on how the temperature and emissivity information is used. Combining real-time performance with multi-wavelength information further provides control system redundancy, higher temperature accuracy, resistance to optical system contamination, and higher reliability that rejects false cold or hot object temperatures. This technology also allows a cost-effective means due to its simple design and small size. This technique can also be easily implemented in existing gas turbine systems without modification of current control hardware and software.

  It should be understood that not necessarily all such objects or advantages described above may be achieved by any particular embodiment. Thus, for example, in a manner that achieves or optimizes one advantage or group of advantages taught herein, without necessarily achieving the other objects or advantages taught or suggested herein. Those skilled in the art will appreciate that the systems and techniques described in can be implemented or implemented.

  Further, those skilled in the art will appreciate that various features of different embodiments can be interchanged. Similarly, the various features described, as well as other known equivalents of each feature, can be mixed and adapted by those skilled in the art, and additional systems and techniques can be constructed in accordance with the principles of the present disclosure.

  Although the invention has been described in detail with respect to a limited number of embodiments, it will be readily understood that the invention is not limited to such disclosed embodiments. Rather, the invention can be modified to incorporate any number of variations, alterations, substitutions or equivalent arrangements not heretofore described, but which are commensurate with the spirit and scope of the invention. Moreover, while various embodiments of the invention have been described, it is to be understood that aspects of the invention can include only some of the described embodiments. Accordingly, the invention should not be limited by the foregoing description, but only by the scope of the appended claims.

  What is desired to be guaranteed by a new and US patent is set forth in the appended claims.

DESCRIPTION OF SYMBOLS 10 Gas turbine system 11 Actuator 12 Fuel injector 14 Fuel supply, fuel 16 Combustor 18 Turbine 19 Shaft 20 Exhaust outlet 22 Compressor, turbine component 24 Air intake 26 Load 30 Air 32 Compressed air 34 Fuel-air mixture 36 Optical Imaging Subsystem, Optical Imaging System, Optical System 38 Optical Connection 39 Viewing Port 40 Wavelength Division Subsystem 41 Sub Wavelength Signal 42 Detector Array 43 Analog Voltage Signal 44 High Speed Multi-Channel Analog to Digital Converter (ADC)
45 Digital voltage signal 46 Smart real-time processing subsystem 52 Built-in communication unit 53 Data 54 Controller 60 Smart real-time radiation temperature measurement system 62 Optical imaging subsystem 64 Optical transmission subsystem 65 Radiation 66 Turbine HGP components, turbine blades 68 Continuous wide wavelength Radiation signal 72 Sub-wavelength signal 92 Detector array 96 Analog voltage signal 97 keyphasor or external trigger unit 98 High-speed multi-channel ADC
99 Digital signal, output 102 Smart real-time processing subsystem 104 Output signal, data 106 Gas turbine controller, I / O interface 108 Actuator 110 Gas turbine 112 Raw digital signal data, raw signal 116 Background correction module 118 Back Ground corrected data 120 Non-uniform correction or gain correction module 122 Non-uniform correction or gain corrected data 124 Bad signal replacement module 126 Data output 132 Calibration module 136 Radiant temperature, data 138 Multi-wavelength algorithm 142 Reflection correction module 146 Reflection Corrected data 152 Raw temperature and emissivity data 156 Smart signal processing algorithm 158 Low level processing 162 High level Processing 164 Signal conditioning 166 Statistical information and trend analysis 168 Control functions, control function module 174 High-speed multi-channel ADC
178 Noise or non-target signal removal 182 Filtering and compensation 186 Log trend 202 Output data 212 Field programmable gate array (FPGA) unit 214 Digital signal processing (DSP) unit 216 Input signal 224 Memory 228 Communication unit 232 Data, signal

Claims (11)

A smart real-time radiation temperature measurement system,
Turbine components,
An optical imaging subsystem configured to receive a continuous wide wavelength radiation signal emitted by the component;
A wavelength division subsystem in optical communication with the optical transmission subsystem, the wavelength division subsystem configured to send the continuous wide wavelength band radiation signal and to divide the radiation signal into a plurality of sub wavelength band signals; ,
At least one detector array in optical communication with the wavelength division subsystem, the at least one detector configured to receive the plurality of sub-wavelength signals and to output a respective analog voltage signal for each of the signals A detector array;
At least one high-speed multi-channel analog-to-digital converter (ADC) electrically coupled to the at least one detector array for digitizing the respective analog voltage signals and outputting digital voltage signals; A configured ADC;
At least one smart real-time processing subsystem electrically coupled to the at least one high-speed multi-channel ADC;
Check and compensate the digital voltage signal;
Calculate the radiance temperature using the reference table,
Calculating the temperature and emissivity of the turbine component based on the radiance temperature, reflection correction, and multi-wavelength algorithm;
Outputting data indicating the temperature, emissivity, and other parameters within a predetermined period of time;
Based on the data, an emergency warning signal is output to control one or more actuators coupled to the gas turbine, either directly or via a controller, to ensure safe operation of the turbine. And a smart real-time radiation temperature measurement system comprising: at least one smart real-time processing subsystem configured as described above. The system of claim 1, wherein the at least one smart real-time processing subsystem sends the alarm signal when the temperature of the part exceeds a predetermined limit. The optical system comprises:
An optical imaging subsystem configured to receive the continuous wide wavelength radiation signal from the gas turbine component;
An optical transmission subsystem configured to send the continuous wide wavelength radiation signal from the optical imaging subsystem;
The system of claim 1, comprising: a wavelength division subsystem that divides the continuous wide wavelength range radiation signal of the turbine component into a plurality of sub wavelength range signals. The system of claim 1, wherein the predetermined period is less than about 10 microseconds. A method for thermal measurement of turbine parts, comprising:
Receiving a continuous wide wavelength radiation signal emitted by the turbine component via an optical imaging subsystem;
Receiving the radiation signal via an optical transmission subsystem;
Dividing the continuous wide wavelength band radiation signal of the turbine component into a plurality of sub wavelength band signals via a wavelength division subsystem;
Receiving the plurality of wavelength band signals via at least one detector array and outputting a respective analog voltage signal for each of the sub-wavelength signals;
Digitizing each respective analog voltage signal via the at least one high-speed multi-channel ADC and outputting a digital voltage signal;
Performing a plurality of processing steps via at least one smart real-time processing subsystem that receives the digital signal;
The plurality of processing steps include:
Inspecting and compensating the digital voltage signal;
Calculating a radiance temperature from a reference table;
Calculating the temperature and emissivity of the turbine component based on the radiance temperature, reflection correction, and a multi-wavelength algorithm;
Outputting data indicative of the temperature, emissivity, and other parameters within a predetermined period of time;
Based on the data, an emergency warning signal is output to control one or more actuators coupled to the gas turbine, either directly or via a controller, to ensure safe operation of the turbine. A method comprising steps and. The method of claim 5, further comprising sending the emergency alert signal when the temperature exceeds a predetermined limit. The method of claim 5, wherein the step of outputting data comprises outputting data in less than about 10 microseconds. A temperature measurement processing system for a turbine component, comprising:
At least one smart real-time processing subsystem electrically coupled to at least one detector array via the at least one high-speed multi-channel ADC;
Receiving a digital voltage signal representing each of a plurality of sub-wavelength signals from the component;
Check and compensate the digital voltage signal;
Calculate the radiance temperature using the reference table,
Calculating the temperature and emissivity of the turbine component based on the radiance temperature, reflection correction, and multi-wavelength algorithm;
Outputting data indicating the temperature, emissivity, and other parameters within a predetermined period of time;
Based on the data, an emergency warning signal is output to control one or more actuators coupled to the gas turbine, either directly or via a controller, to ensure safe operation of the turbine. A temperature measurement processing system comprising a real-time processing subsystem configured as described above. The temperature measurement system of claim 8, wherein the at least one smart processing subsystem sends an alarm signal when the temperature exceeds a predetermined limit. The temperature measurement system of claim 8, wherein the predetermined period comprises less than about 10 microseconds. An optical imaging subsystem configured to receive a continuous wide wavelength radiation signal emitted by the turbine component;
An optical transmission subsystem configured to send the continuous wide wavelength radiation signal from the optical imaging subsystem to the wavelength division subsystem;
A wavelength division subsystem that divides the continuous wide wavelength radiation signal of the turbine component into a plurality of sub-wavelength signals;
At least one detector array in optical communication with the wavelength division subsystem, the at least one detector configured to receive the plurality of sub-wavelength signals and to output a respective analog voltage signal for each of the signals A detector array;
At least one high-speed multi-channel analog-to-digital converter (ADC) electrically coupled to the at least one detector array for digitizing the respective analog voltage signals and digitalizing them to the smart real-time processing subsystem; The temperature measurement system of claim 8, further comprising: an ADC configured to output a voltage signal.

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