• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    The invention relates to an apparatus, a system and a method for determining a target exhaust temperature for a gas turbine (10). The method includes establishing a desired exhaust temperature based at least in part on a compressor pressure condition; establishing a value of a temperature adjustment for the target exhaust temperature based at least in part on a vapor moisture basis; and a change in the target exhaust temperature based at least in part on the value of the temperature adjustment.
    公开号:CH706985B1
    申请号:CH01627/13
    申请日:2013-09-24
    公开日:2017-07-14
    发明作者:Simons Derrick；Dean Douglas；Romoser Carey；Wilkes Kevin；Kulkarni Abhijit；Popovic Predrag
    申请人:Gen Electric；
    IPC主号:
    专利说明:

    Description Field of the Invention This invention relates generally to gas turbines, and more particularly to systems and methods for establishing a target exhaust gas temperature for gas turbine control.
    Background of the Invention In some gas turbines, steam injection may be used to lower the temperature to thereby allow the injection of additional fuel into the gas turbine resulting in additional power output. However, the delivery of steam into the gas turbine may affect the emissions of the gas turbine. For example, when steam is injected into a gas turbine using a dry-low-NOx (DLN) combustion system, problems with combustion stability and / or emissions compliance may arise. That is, the injection of steam can significantly affect the combustion process, which generally can lead to poor performance and emissions. A target exhaust gas temperature for the control of the gas turbine is therefore suitable to set.
    Brief Description of the Invention Some or all of the above requirements and / or problems may be solved by the invention. The described embodiments include systems and methods for establishing a desired exhaust gas temperature for the control of a gas turbine. According to one aspect of the invention, a method is provided for determining a target exhaust gas temperature for the control of a gas turbine.
    The method for setting a target exhaust temperature for the control of a gas turbine comprising a compressor in which a compressor pressure prevails, and which comprises a steam injector for generating steam moisture comprises the steps of: a) determining a compressor pressure state; and b) setting a target exhaust gas temperature based at least in part on the determined compressor pressure condition; c) determining the vapor moisture; d) determining a value of a temperature adjustment for the target exhaust gas temperature based at least in part on vapor moisture; and e) changing the target exhaust gas temperature determined in step b) based at least in part on the value of the temperature adjustment.
    In addition, the method may be such that the determination of the temperature adjustment is further based on at least one of: a CO or NOx emission reference state.
    The determination of the temperature adjustment may further be based, at least in part, on a specific humidity at a turbine inlet.
    Alternatively, the determination of the temperature adjustment may further be based, at least in part, on a differential inlet pressure loss, a current compressor condition, and a differential exhaust gas temperature output.
    Further, alternatively, the determination of the temperature adjustment may be based, at least in part, on a differential back pressure, a current compressor condition, and a differential exhaust gas temperature output.
    [0009] Each method mentioned above may further comprise the steps of: - setting a plurality of different target exhaust gas temperatures; and selecting one of the plurality of different target exhaust gas temperatures as the target exhaust gas temperature set for the control of the gas turbine to enable control of the gas turbine.
    The target exhaust temperature may be applied to a controller to determine a turbine firing temperature.
    Additionally or alternatively, the desired exhaust temperature may be applied to a controller to determine the fuel flow and / or air flow to a combustor of the gas turbine.
    Each method mentioned above may be repeated periodically during operation of the gas turbine.
    According to a further aspect of the invention, an apparatus for setting a target exhaust gas temperature for the control of a gas turbine is specified.
    The device for setting a target exhaust gas temperature for the control of a gas turbine comprises: - a controller with a computer processor; and a memory in communication with the computer processor operable to store computer-executable instructions operable to: set a target exhaust temperature based at least in part on a compressor pressure condition; set a value of a temperature adjustment for the target exhaust gas temperature based at least in part on vapor moisture; and to change the target exhaust gas temperature based at least in part on the value of the temperature adjustment.
    The apparatus may further determine the temperature adjustment based on at least one of a CO and a NOx reference state.
    Additionally or alternatively, the apparatus may further determine the temperature adjustment based at least in part on a specific humidity at the turbine inlet.
    Additionally or alternatively, the apparatus may further determine the temperature adjustment based at least in part on a differential inlet pressure loss, a current compressor condition, and a differential exhaust gas temperature output.
    Additionally or alternatively, the apparatus may further determine the temperature adjustment based at least in part on differential back pressure, current compressor status, and differential exhaust gas temperature output.
    The apparatus may set a plurality of different target exhaust temperatures and select one of the plurality of different target exhaust temperatures as the target exhaust gas temperature set for the control of the gas turbine to enable control of the gas turbine.
    In each of the aforementioned devices, the controller may apply the target exhaust temperature for determining a turbine firing temperature.
    In any of the aforementioned devices, the controller may apply the target exhaust gas temperature to determine a fuel flow and / or air flow to a combustor of the gas turbine.
    In any of the aforementioned devices, the computer-executable instructions may be periodically repeated during operation of the gas turbine.
    Furthermore, according to a further aspect of the invention, a system for setting a target exhaust gas temperature for a gas turbine is specified. The system includes: a gas turbine having one or more compressors, one or more burners, one or more turbines, a steam source for injecting steam into pre-combustion / post-compression air, a controller having a computer processor, and a memory in In connection with the computer processor operable to store computer-executable instructions operable to: set a target exhaust temperature based at least in part on a compressor pressure condition; set a value of a temperature adjustment for the target exhaust gas temperature based at least in part on vapor moisture; and to change the target exhaust gas temperature based at least in part on the value of the temperature adjustment.
    In the system, the determination of the value of the temperature adjustment may be further achieved on the basis of at least one of: a CO and a NOx emission reference state.
    Further embodiments, aspects and features of the invention will become apparent to those skilled in the art from the following detailed description, the accompanying drawings and the appended claims.
    Brief Description of the Drawings Referring now to the attached drawings, which are not necessarily drawn to scale, and in which:
    FIG. 1 is an exemplary schematic illustration of a system for setting a target exhaust gas temperature for a gas turbine according to an embodiment of the invention; FIG.
    FIG. 2 is a schematic diagram illustrating details of an exemplary data flow for establishing a target exhaust gas temperature for a gas turbine in accordance with an embodiment of the invention. FIG.
    3 is a schematic diagram illustrating details of an exemplary data flow for establishing a target exhaust gas temperature for a gas turbine in accordance with an embodiment of the invention.
    4 is a schematic diagram illustrating details of an exemplary data flow for establishing a target exhaust gas temperature for a gas turbine in accordance with an embodiment of the invention.
    5 is a schematic diagram illustrating details of an exemplary data flow for determining a target exhaust gas temperature for a gas turbine according to an embodiment of the invention.
    6 is a schematic diagram illustrating details of an exemplary data flow for establishing a target exhaust gas temperature for a gas turbine in accordance with an embodiment of the invention.
    Detailed Description of the Invention Illustrative aspects of the invention will now be described more fully hereinafter with reference to the accompanying drawings, in which some but not all aspects of the invention are shown. In fact, the invention may be embodied in many different forms, and should not be considered as limited to those aspects described herein; instead, these aspects are provided so that this disclosure meets the applicable legal requirements. Like reference numerals refer to like elements throughout the specification and drawings.
    Illustrative embodiments of the invention are directed, inter alia, to systems and methods for establishing a target exhaust gas temperature for a gas turbine. Certain illustrative embodiments of the invention may be directed to injection of steam in pre-combustion / recompression air. In some embodiments, a desired exhaust temperature may be determined based at least in part on a compressor pressure condition. In other cases, the desired exhaust temperature may be changed at least in part based on the temperature adjustment.
    In one embodiment, the temperature adjustment may be further determined based on at least one of: a CO and a NOx emission reference state. In one embodiment, the temperature adjustment may further be determined at least in part based on specific humidity at the turbine inlet. In yet another embodiment, the temperature adjustment may determine at least in part based on a differential inlet pressure loss, a current compressor status, and / or a differential exhaust gas temperature output. Also, in some cases, the determination of the temperature adjustment may be determined based at least in part on a differential backpressure, a current compressor state, and a differential exhaust temperature output.
    In certain aspects, multiple preliminary target exhaust temperatures may be generated. In this way, in some cases, one or more preliminary target exhaust temperatures may be selected to enable control of the gas turbine. In other aspects, the desired exhaust temperature may be applied by a controller to determine a turbine firing temperature. Also, in some examples, the target exhaust temperature may be applied by a controller to determine a fuel flow and / or air flow to a combustor of the gas turbine. In any case, the systems and methods described may be repeated periodically during operation of the gas turbine.
    Certain embodiments of the invention may provide a technical solution for establishing a target exhaust gas temperature for a gas turbine. For example, the systems and methods described herein may provide for adaptation of a predicted gas turbine exhaust temperature. In some cases, the adjusted target exhaust gas temperature may allow compliance with emissions (e.g., NOx and CO) that offset the injection of steam in pre-combustion / re-compression air. For example, in certain embodiments, a turbine steam flow measurement may be used to determine an adjustment that may be applied to an existing humidity term in a NOx and / or CO limit algorithm. In this way, the predictive emission limit exhaust gas temperatures may be adjusted in the appropriate mass with respect to the steam flow rate. These temperatures may be used elsewhere in the control algorithm to adjust the turbine fuel and / or airflow to achieve emissions compliance.
    In an illustrative embodiment, FIG. 1 illustrates a gas turbine 10 having a compressor 12, a combustor 14, a turbine 16 drivingly connected to the compressor 12, and a control system 18. An inlet 20 to the compressor 12 may Supply ambient air and possibly injected into the compressor 12 water. The inlet may include passages, filters, screens, and sound absorbing devices, each of which may contribute to a pressure loss of the ambient air flowing through the inlet 20 into the inlet guide vanes 21 of the compressor 12. An exhaust passage 22 for the turbine may pass combustion gases from the outlet of the turbine 16 through passages including, for example, emission control and sound absorption devices. The exhaust passage 22 may exert a back pressure on the turbine 16. The amount of back pressure may vary over time due to the addition of components to the passage 22 and due to dust and dirt clogging of the exhaust passages. In one example, the turbine may drive a generator 24 that generates electrical power. In other cases, however, the turbine may be associated with mechanical drive applications. The inlet loss to the compressor 12 and the turbine exhaust pressure losses may tend to be a function of a corrected flow through the gas turbine engine 10. As a result, the amount of inlet loss and turbine back pressure may vary with the flow through the gas turbine engine 10.
    In certain embodiments, a steam injector 11 may inject steam into the pre-combustion post-compression air. In some cases, the steam injected by the steam injector 11 may be used to lower the temperature so that additional fuel may be injected into the gas turbine engine 10, which may increase the power output of the gas turbine engine 10.
    The operation of the gas turbine 10 may be monitored by various sensors that detect various components and conditions of the gas turbine 10, the generator 24, and / or the environment. For example, temperature sensors may monitor the environment surrounding the gas turbine, the compressor outlet temperature, the turbine exhaust temperature, and other temperature readings of the gas flow through the gas turbine engine 10. In some examples, pressure sensors may monitor ambient pressure and static and dynamic pressure levels at the compressor inlet and outlet and the turbine gas, as well as at other locations in the gas flow. Further, in other examples, humidity sensors (e.g., wet and dry bulb thermometers) may measure the ambient humidity in the inlet channel of the compressor. In some cases, the sensors 26 may also include flow sensors, velocity sensors, flame detector sensors, valve position sensors, guide vane angle sensors, or the like that measure various parameters related to the operation of the gas turbine engine 10. As used herein, "parameters" and similar terms refer to elements that may be used to control the operating conditions of the gas turbine engine 10, such as those shown in FIG. Temperatures, pressures, and flows at defined locations in the gas turbine engine 10 that may be used to represent a given turbine operating condition.
    A fuel control system 28 may control the fuel flowing from a fuel supply to the burner 14, a division between the fuel flowing into the main nozzles and the fuel mixed with air before flowing into a combustion chamber, and the type of fuel for the fuel Select burner 14. The fuel control system 28 may be a separate unit or may be a component of a larger controller 18. For example, in some instances, controller 18 may be a computer system having a processor (s) 19 executing programs to control the operation of gas turbine engine 10 using sensor input signals and instructions from an operator. The programs executed by the controller 18 may include a scheduling algorithm for controlling fuel flow and / or air flow to the burner 14. The commands generated by the controller may cause actuators of the gas turbine engine 10 to adjust, for example, valves between the fuel supply and the combustor 14 that regulate the flow and type of fuel, inlet guide vanes 21 on the compressor 12, and other control settings on the gas turbine 10.
    The controller 18 may control the gas turbine 10 based at least in part on algorithms stored in a computer memory 14 of the controller. These algorithms may cause the controller 18 to maintain the NOx and CO emissions in the turbine exhaust within certain predetermined limits and to maintain the burner burn temperatures within predetermined temperature limits. The algorithms may include parameters for the current compressor pressure ratio, ambient environmental humidity, inlet pressure loss, and / or turbine exhaust back pressure. Because of these parameters in the algorithms, controller 18 may, among other things, apply the injection of steam into the pre-combustion / recompression air through the steam injector 11.
    In certain embodiments, the burner 14 may be a DLN combustion system. Further, in some cases, the control system 18 may be programmed and / or modified to control the DLN combustion system. Exemplary DLN combustion control algorithms are shown in Figs. 2-6.
    In an illustrative embodiment, FIG. 2 is a block diagram illustrating an exemplary data flow 34, such as a limiting turbine exhaust temperature based on a NOx emission control process 36, a CO emission control process 38, a target turbine combustion temperature (TFeUer) process 40 and a TFeuerBegrenzungsprozesses 42 set. The processes 36, 38, 40 and 42 may each output a separate desired target turbine exhaust temperature. In some cases, the process 34 may include a selection logic 44 to select one of the desired desired exhaust gas temperatures entered. For example, in certain aspects, the process 34 may be used to keep turbine emissions and firing temperatures at or below limits, particularly when environmental conditions, inlet pressure loss, exhaust back pressure, and / or steam injection vary. Additionally, in other aspects, the process 34 may enable smooth transitions in the operation of the gas turbine engine 10 when changes in ambient conditions occur as steam is injected into the gas turbine and as the inlet pressure loss and back pressure vary.
    FIG. 3 is a schematic representation of a process 45 that may, in some cases, represent any of the processes 36, 38, 40, and 42 that produce a target turbine exhaust temperature 46. The NOx, CO and TF control processes and the TF control setpoint processes may each have their own specific schedules and correction factor exponents, but are otherwise similar and represented by the process 45. For example, in one example, the processes may receive, as input data, the current compressor pressure ratio, the specific humidity of the ambient air entering the compressor 12, the pressure loss of the ambient air flowing through the intake passage 20, and the turbine exhaust back pressure due to the exhaust passage 22. In particular
    Aspects may generate a desired target exhaust temperature 46 based on these input values, the N0X, CO and TF control processes 36, 38 and 42, and the TF control setpoint process, respectively.
    In an illustrative embodiment, the representative process 45 may include a map 48 for applying a compressor pressure ratio to achieve a corrected turbine exhaust temperature 50. For example, the compressor pressure ratio, as a function of the exhaust temperature setpoint schedule 48, may be a graph, a look-up table, or a function that correlates the compressor pressure ratio with a corrected exhaust temperature setpoint. In some cases, the plan 48 may be generated for each gas turbine or gas turbine class in a conventional manner. In this way, the schedule 48 may provide a corrected exhaust temperature for a defined reference load and / or environmental conditions, such as a minimum flow rate. Humidity and temperature, yield.
    In order to obtain the desired actual exhaust gas temperature, the corrected exhaust gas temperature may be adjusted to take into account the load, the ambient temperature and the humidity and the injected steam. For example, in one illustrative embodiment, the corrected exhaust temperature 50 (after being adjusted to account for compressor inlet pressure loss and exhaust back pressure) may be set to an absolute temperature level, such as, for example, FIG. be converted to grade Rankine, in step 52. That is, a Fahrenheit temperature can be converted to Rankine by adding 459.67 degrees. The absolute temperature may then be multiplied at step 54 by a correction factor 56, which may be a function (Xy) of a correction factor exponent (y) and a compressor temperature ratio (X). The correction factor exponent (y) may be obtained empirically and be specific to each algorithm 36, 38, 40 and 42 and to each class of gas turbine 10. The compressor temperature ratio (X) may be an indication of a gas turbine load. The compressor temperature ratio may be the actual compressor outlet temperature above a reference compressor temperature (Tref), such as a compressor. be the compressor temperature at full gas turbine load. The temperatures used for the compressor temperature ratio may be absolute temperatures. By multiplying the function (xv) and the corrected target exhaust gas temperature, an uncorrected target exhaust gas temperature 58 converted to a non-absolute temperature scale can be generated.
    The corrected turbine exhaust temperature 50 output from the compressor pressure ratio map 48 does not take into account deviations in the compressor inlet pressure loss, exhaust back pressure loss, changes in ambient humidity, changes due to injection of steam and / or units of gas turbine engine specific deviations 10. Additional schedules 60, 62, 100 and 200 may be applied to adjust the target turbine exhaust temperatures with respect to changes in these conditions. For example, the inlet pressure loss map 60 may be a function that correlates with a differential exhaust gas temperature to the actual compressor pressure ratio and compressor inlet pressure (or the change between the actual inlet pressure ratio and the defined inlet pressure loss applied in the development of the compressor map 48 For example, the intake pressure loss schedule 60 may be a function of a compressor ratio because the pressure ratio is a function of the corrected flow through the gas turbine 10 and varies with the load on the gas turbine 10. For example, the differential exhaust temperature value 66 output from the intake pressure loss schedule 60 may be a corrected temperature value the differential exhaust gas temperature 66 is summed with the corrected desired exhaust gas temperature 50 obtained from the compressor map 48.
    Similarly, in certain embodiments, the back pressure map 62 may provide a corrected exhaust temperature difference value 50 based on a function of the compressor pressure ratio and the actual back pressure (or the change between the actual back pressure and the defined back pressure applied in the development of the plan 48 ) produce. For example, the back pressure map 42 may be a function of the compressor ratio because the turbine back pressure loss is a function of the corrected flow rate through the gas turbine and varies with the load on the gas turbine.
    For example, in certain cases, the compressor outlet pressure 104 may be multiplied by a constant 106 to determine a total flow rate 102 of the compressor that has a combined flow rate of air and air of the steam. Thereafter, the vapor flow rate 108 may be subtracted from the total flow rate 102 to determine the air flow rate 110. Further, the vapor flow rate 108 may be divided by the air flow rate 110 to determine the water concentration 112. The water concentration 112 may then be multiplied by a constant 116, which is a calibration factor that is application specific to determine the vapor moisture 118. The vapor moisture 118 may then be summed with the inlet ambient humidity 120. The summed steam humidity 118 and inlet ambient humidity 120 may then be multiplied by a variable 122 to convert the summed humidity to a differential temperature 124 that may be applied to adjust the target turbine exhaust temperature with respect to injected steam and ambient humidity conditions. For example, the differential temperature 124 may be a positive or negative value. In some cases, the variable 122 may include the compressor pressure ratio 126, which may be squared and / or multiplied by one or more constants 328, 130 and 132 and / or summed.
    FIG. 5 illustrates an example embodiment of the calibration plan 200. For example, an adjustment of the CO limit may be determined by setting a desired CO value at step 202. The desired CO level 202 may be multiplied by a limit reference state 204 in ppm. Subsequently, the multiplied
    权利要求:
    Claims (10)
    [1]
    Set point 202 and limit 204 may be applied to a CO limit application map 206 to derive corrected turbine exhaust temperature. FIG. 6 is a schematic diagram that compresses the information of FIG. 3 into blocks for each of the algorithms illustrated in FIG. 2. FIG. 6 illustrates that the representative algorithm 45 may be adapted and applied to each of the algorithms 36, 38, 40, and 48. The select logic 44 may include a maximum select logic unit 68 that may identify the hottest temperature between the target exhaust temperature 46 from the CO limiting algorithm 38 and the target TF control algorithm 40. The hottest temperature identified by the maximum selection 68 may be applied to a minimum select logic unit 70 that identifies the coolest of the temperatures output by the maximum select logic unit 68, the uncorrected target exhaust gas values from the NOx limitation algorithm, and the TFeed constraint algorithm and a maximum exhaust temperature value 72. The output of the minimum select logic unit 70 may be applied as the uncorrected target turbine exhaust 74. The controller 18 may adjust the fuel control to achieve the target turbine exhaust gas value 74. The selection logic 44 may also provide a smooth transition in the target turbine exhaust during a transition from a selected limiting algorithm to the selection of a different algorithm as operating conditions change. The selection of the exhaust gas set points may indirectly specify the required burner burn temperature and the value of the alternative emission when the schedule is in effect. claims
    A method of determining a target exhaust gas temperature for the control of a gas turbine, comprising a compressor (12) in which a compressor pressure prevails, and comprising a steam injector (11) for generating steam moisture, comprising the steps of: a) determining a compressor pressure condition; and b) setting a target exhaust gas temperature based at least in part on the determined compressor pressure condition; c) determining the vapor moisture; d) determining a value of a temperature adjustment for the target exhaust gas temperature based at least in part on vapor moisture; and e) changing the target exhaust gas temperature determined in step b) based at least in part on the value of the temperature adjustment.
    [2]
    2. The method of claim 1, wherein determining the temperature adjustment further is based on at least one of a CO or NOx emission reference state, turbine inlet specific humidity, differential inlet pressure loss, current compressor status, differential exhaust gas temperature, differential back pressure, and differential exhaust gas temperature.
    [3]
    3. The method of claim 1 or 2, further comprising the steps of: establishing a plurality of different target exhaust gas temperatures; and selecting one of the plurality of different target exhaust gas temperatures as the target exhaust gas temperature set for the control of the gas turbine to enable control of the gas turbine.
    [4]
    4. The method of claim 1, wherein the target exhaust gas temperature is applied by a controller to determine at least one of: a turbine firing temperature, a fuel flow and / or air flow to a combustor of the gas turbine.
    [5]
    5. The method according to any one of the preceding claims, wherein the method is repeated periodically during operation of the gas turbine.
    [6]
    6. A device for determining a target exhaust gas temperature for controlling a gas turbine, which comprises a compressor (12) in which a compressor pressure prevails, and which comprises a steam injector (11) for generating steam moisture, said device comprising: a controller (18) a computer processor; and a memory in communication with the computer processor operable to store computer-executable instructions operable to: set a target exhaust temperature based at least in part on a compressor-pressure-state basis; set a value of a temperature adjustment for the target exhaust gas temperature at least in part based on vapor moisture, and to change the target exhaust gas temperature based at least in part on the value of the temperature adjustment.
    [7]
    7. The apparatus of claim 6, wherein the determination of the temperature adjustment is further based on at least one of: a CO or NOx reference state; a specific humidity at the turbine inlet; a differential intake pressure loss, a current compressor state, a differential exhaust gas temperature output, and a differential back pressure.
    [8]
    8. The apparatus of claim 6 or 7, wherein the target exhaust gas temperature is applied by the controller to determine a turbine firing temperature, a fuel flow and / or air flow to a burner of the gas turbine.
    [9]
    9. A system, comprising: a gas turbine having one or more compressors (12), one or more burners, one or more turbines (10); a steam source (11) for injecting steam into precombustion / post-compression air; a controller (18) having a computer processor; and a memory in communication with the computer processor operable to store computer-executable instructions operable to: set a target exhaust temperature based, at least in part, on a compressor pressure condition; set a value of a temperature adjustment for the target exhaust gas temperature based at least in part on vapor moisture; and to change the target exhaust gas temperature based at least in part on the value of the temperature adjustment.
    [10]
    10. The system of claim 9, wherein the determination of the value of the temperature adjustment is further based on at least one of: a CO emission reference state and a NOx emission reference state.
    类似技术:
    公开号 | 公开日 | 专利标题
    CH706985B1|2017-07-14|Method, apparatus and system for determining a target exhaust gas temperature for a gas turbine.
    DE102014108832A1|2015-01-08|Systems and methods for controlling a gas turbine
    DE102014103084A1|2014-09-18|Systems and methods for gas turbine tuning and control
    EP2449234B1|2013-07-31|Method for regulating a gas engine
    DE102008002941A1|2009-02-05|Wobbe control and improved operability through in-line fuel conversion
    WO2016170063A1|2016-10-27|Method and device for the model-based optimization of a technical apparatus
    DE102007009791A1|2007-08-30|Variable extraction for gas turbine load regulation involves changing quantity of compressed air extracted from turbine compressor depending on demanded load for gas turbine
    DE102007010638A1|2007-09-13|Variable extraction procedures and systems for compressor protection
    CH701015A2|2010-11-15|Methods and systems to remove deposits in a gas turbine engine for the generation of dynamic combustion processes.
    EP1959115B1|2018-07-25|Method for determination of the water content in the working fluid of a gas turbine
    DE112014001000T5|2015-11-12|Gas turbine system, control and gas turbine operation method
    DE112007000409B4|2012-07-19|Method for controlling turbine outlet temperatures in a diesel engine
    CH708386A2|2015-01-30|System and method for control of gas turbine emissions.
    AT516134A2|2016-02-15|Internal combustion engine with a control device
    DE102013114904A1|2014-07-03|Gas turbine and method for controlling a gas turbine under partial load condition
    DE112015003596T5|2017-06-08|FLOW VOLUME RATIO CALCULATION DEVICE, SELF-EQUIPPED CONTROL DEVICE, GAS TURBINE SYSTEM EQUIPPED WITH THIS CONTROL DEVICE, FLOW VOLUME RATIO CALCULATION METHOD, AND FUEL LINE CONTROL METHOD
    DE102014116551A1|2015-05-21|Automated commissioning of a gas turbine combustion control system
    DE102016123524A1|2017-06-22|Application of a combined likelihood control in setting the output parameters of a gas turbine with a scaling factor, related control systems, computer program products and methods
    DE112015003604T5|2017-04-20|FLOW RATIO CALCULATION DEVICE, SELF-PROVIDED CONTROL DEVICE, GAS TURBINE SYSTEM PROVIDED BY SAID CONTROL DEVICE, FLOW RATIO CALCULATION METHOD, AND METHOD FOR CONTROLLING THE FUEL SYSTEM
    DE10256241A1|2004-06-09|Method and device for controlling an internal combustion engine having exhaust gas recirculation
    DE112014003023T5|2016-03-17|Compressor corrected RPM calculation method, compressor control method and apparatus for implementing these methods
    AT515769A2|2015-11-15|Internal combustion engine and method of operation thereof
    DE102015119974A1|2016-05-19|Application of probabilistic control in setting a gas turbine with a measurement error, related control systems, computer program products and methods
    DE102013110199A1|2015-03-19|Apparatus and method for supplying an internal combustion engine with a conditioned combustion gas
    DE202017000267U1|2018-04-19|System for determining a desired position parameter value for a pneumatically operated bypass valve of an exhaust gas turbocharger
    同族专利:
    公开号 | 公开日
    CH706985A2|2014-03-31|
    DE102013110068A1|2014-04-03|
    US9297315B2|2016-03-29|
    CH706985A8|2014-08-29|
    CN103711556A|2014-04-09|
    CN103711556B|2018-05-15|
    US20140090353A1|2014-04-03|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    DE4446543A1|1994-12-24|1996-06-27|Abb Management Ag|Power plant|
    US6715916B2|2001-02-08|2004-04-06|General Electric Company|System and method for determining gas turbine firing and combustion reference temperatures having correction for water content in fuel|
    EP1462633B1|2003-03-28|2013-10-30|Siemens Aktiengesellschaft|Method of controlling the hot gas temperature of a gas turbine|
    US6912856B2|2003-06-23|2005-07-05|General Electric Company|Method and system for controlling gas turbine by adjusting target exhaust temperature|
    DE102007008296A1|2007-02-16|2008-08-21|Alstom Technology Ltd.|Method for automatically controlling one or more firing temperatures of a gas turbine plant and method for determining the water content in the exhaust gas of a gas turbine plant|
    MX349492B|2009-06-04|2017-08-01|Excel Thermic Llc|Internal combustion engine.|
    US8459243B2|2009-07-31|2013-06-11|Ford Global Technologies, Llc|Method, systems and sensor for detecting humidity|
    US8387358B2|2010-01-29|2013-03-05|General Electric Company|Gas turbine engine steam injection manifold|WO2014072842A1|2012-11-06|2014-05-15|Al Mahmood Fuad|Reducing the load consumed by gas turbine compressor and maximizing turbine mass flow|
    US9599028B2|2014-09-08|2017-03-21|General Electric Company|Bulk flame temperature regulator for dry low emission engines|
    JP6364363B2|2015-02-23|2018-07-25|三菱日立パワーシステムズ株式会社|Two-shaft gas turbine and control device and control method thereof|
    US10330015B2|2015-09-25|2019-06-25|General Electric Company|Transient emission temperature control of turbine systems|
    US9739199B2|2015-10-30|2017-08-22|General Electric Company|Intercooled gas turbine optimization|
    WO2017096144A1|2015-12-04|2017-06-08|Powerphase Llc|Gas turbine firing temperature control with air injection system|
    JP6706936B2|2016-03-09|2020-06-10|三菱日立パワーシステムズ株式会社|Gas turbine control device and gas turbine control method|
    EP3225812B1|2016-03-29|2019-02-27|Mitsubishi Hitachi Power Systems, Ltd.|A two-shaft gas turbine, and the control method of opening degree of inlet guide vane of the gas turbine|
    US11112118B2|2016-06-27|2021-09-07|General Electric Company|Gas turbine lower heating value methods and systems|
    JP6795419B2|2017-02-06|2020-12-02|三菱パワー株式会社|Moisture utilization gas turbine|
    EP3457030A1|2017-09-18|2019-03-20|Siemens Aktiengesellschaft|Controller and method|
    法律状态:
    2014-08-29| PK| Correction|Free format text: ERFINDER BERICHTIGT. |
    2017-03-15| NV| New agent|Representative=s name: GENERAL ELECTRIC TECHNOLOGY GMBH GLOBAL PATENT, CH |
    2021-04-30| PL| Patent ceased|
    优先权:
    申请号 | 申请日 | 专利标题
    US13/630,610|US9297315B2|2012-09-28|2012-09-28|Systems and methods for determining a target exhaust temperature for a gas turbine|
    [返回顶部]