Abstract: A method for block loading an electrical grid with a combined cycle power plant (CCPP) includes operating a gas turbine system of the CCPP in an islanding mode with a steam turbine system of the CCPP off line with turning gear rotating only; loading the steam turbine system accordingly to temperature matching conditions of the steam turbine system, the loading of the steam turbine system includes controlling gas turbine exhaust fed to the steam turbine system and the gas turbine exhaust temperature heats the steam turbine system and to meet temperature matching conditions of the steam turbine system; wherein controlling gas turbine exhaust includes controlling fuel flow and air flow to the gas turbine system; and operating at least one of the gas turbine system and steam turbine system to block load the electrical grid from a load on at least one of gas turbine system and steam turbine system.

Abstract: A method of detecting flame state of a combustor of a turbine engine. The method includes determining at least one of a first derivative and a second derivative of a compressor discharge pressure of a compressor of the turbine engine; determining at least one of a first derivative and a second derivative of a gas turbine exhaust gas temperature of the exhaust gases output by the turbine engine; determining at least one of a first derivative and a second derivative of a gas turbine shaft/rotor speed of the turbine engine; determining at least one of a first derivative and a second derivative of combustor dynamic pressure monitoring; and determining a flame state of a combustor of the turbine engine based on the combustor dynamic pressure monitoring, the determined derivatives of the combustion dynamics, compressor discharge pressure, gas turbine shaft/rotor speed, and gas turbine exhaust gas temperature of the exhaust gases.

Abstract: A method for block loading an electrical grid with a combined cycle power plant (CCPP) includes operating a gas turbine system of the CCPP in an islanding mode with a steam turbine system of the CCPP off line with turning gear rotating only; loading the steam turbine system accordingly to temperature matching conditions of the steam turbine system, the loading of the steam turbine system includes controlling gas turbine exhaust fed to the steam turbine system and the gas turbine exhaust temperature heats the steam turbine system and to meet temperature matching conditions of the steam turbine system; wherein controlling gas turbine exhaust includes controlling fuel flow and air flow to the gas turbine system; and operating at least one of the gas turbine system and steam turbine system to block load the electrical grid from a load on at least one of gas turbine system and steam turbine system.

Abstract: A method of detecting flame state of a combustor of a turbine engine. The method includes determining at least one of a first derivative and a second derivative of a compressor discharge pressure of a compressor of the turbine engine; determining at least one of a first derivative and a second derivative of a gas turbine exhaust gas temperature of the exhaust gases output by the turbine engine; determining at least one of a first derivative and a second derivative of a gas turbine shaft/rotor speed of the turbine engine; determining at least one of a first derivative and a second derivative of combustor dynamic pressure monitoring; and determining a flame state of a combustor of the turbine engine based on the combustor dynamic pressure monitoring, the determined derivatives of the combustion dynamics, compressor discharge pressure, gas turbine shaft/rotor speed, and gas turbine exhaust gas temperature of the exhaust gases.

Abstract: A method of controlling an operating temperature of a first combustion zone of a combustor of a rotary machine includes determining a current operating temperature and a target operating temperature of a first combustion zone using a digital simulation. The method further includes determining a derivative of the current operating temperature with respect to a current fuel split using the digital simulation. The fuel split apportions a total flow of fuel to the combustor between the first combustion zone and a second combustion zone. The method also includes calculating a calculated fuel split that results in a calculated operating temperature approaching the target operating temperature. The method further includes channeling a first flow of fuel to the first combustion zone and a second flow of fuel to the second combustion zone.

Abstract: A method of controlling an operating temperature of a first combustion zone of a combustor of a rotary machine includes determining a current operating temperature and a target operating temperature of a first combustion zone using a digital simulation. The method further includes determining a derivative of the current operating temperature with respect to a current fuel split using the digital simulation. The fuel split apportions a total flow of fuel to the combustor between the first combustion zone and a second combustion zone. The method also includes calculating a calculated fuel split that results in a calculated operating temperature approaching the target operating temperature. The method further includes channeling a first flow of fuel to the first combustion zone and a second flow of fuel to the second combustion zone.

Abstract: Presented herein are turbine machines, turbine control systems, methods, and computer-readable storage devices for controlling turbines including a compressor, a combustion system, and a turbine section comprising a turbine operating at an initial turbine output while using initial parameter values for the respective control parameters of the turbine. The techniques involve, for respective selected control parameters, selecting an adjustment of the initial parameter value of the selected control parameter, and predicting a predicted turbine output of the turbine operated using the adjustment of the selected control parameter and the initial parameter values for other control parameters; comparing the predicted turbine outputs for the adjustments of the respective control parameters to select, from the control parameters, a target control parameter having a target adjustment that results in the target turbine output; and operating the turbine with the target adjustment of the target control parameter.

Abstract: A system includes a controller configured to control one or more parameters of a gas turbine engine based on a feedback and a predicted lifespan of one or more components of the gas turbine engine to substantially maintain at least one of power output or heat rate above a threshold level in response to degradation or fouling of the gas turbine engine.

Abstract: Methods and systems for detecting an oscillatory event are provided. According to one embodiment, a system may include a controller configured to provide a command signal to a positioning device and a processor communicatively coupled to the controller. The command signal may include a reference position. The processor may be configured to monitor a feedback signal responsive to the command signal. The feedback signal may include an actual position of the positioning device. The processor may be further configured to determine that within a predetermined period of time the actual position is both above a predetermined upper threshold and below a predetermined lower threshold. Based on the determination, the processor may declare the oscillatory event.

Abstract: Methods and systems for detecting an oscillation error are provided. According to one embodiment, a system may include a controller, and a processor communicatively coupled to the controller. The processor may be configured to detect an oscillatory event and increment a delay timer based on a duration of the oscillatory event. The delay timer may be set to a predetermined delay value. Additionally, the processor may be configured to determine that the delay timer exceeds the predetermined delay value and, based on the determination, declare the oscillation error.

Abstract: Presented herein are turbine machines, turbine control systems, methods, and computer-readable storage devices for controlling turbines including a compressor, a combustion system, and a turbine section comprising a turbine operating at an initial turbine output while using initial parameter values for the respective control parameters of the turbine. The techniques involve, for respective selected control parameters, selecting an adjustment of the initial parameter value of the selected control parameter, and predicting a predicted turbine output of the turbine operated using the adjustment of the selected control parameter and the initial parameter values for other control parameters; comparing the predicted turbine outputs for the adjustments of the respective control parameters to select, from the control parameters, a target control parameter having a target adjustment that results in the target turbine output; and operating the turbine with the target adjustment of the target control parameter.

Abstract: A power system includes a gas turbine configured to rotate a shaft to supply power to an electricity grid and a controller configured to detect a change in a speed of the shaft and to adjust a formula for controlling a fuel supplied to a combustor of the gas turbine based on detecting a changing shaft speed.

Abstract: A load protection system for a turbine is provided. The turbine has a load floor representing a lowest allowable load the turbine generally operates above. The turbine supplies power to an electrical grid. The grid has a grid frequency where as the grid frequency increases the turbine sheds load. The load protection system includes a controller in communication with the turbine and the electrical grid. The controller has a memory for storing a commanded target turbine load. The commanded target turbine load is the load the turbine operates at the load floor. The controller includes control logic for sending a flag to a variable rate limiter and a commanded load control block. The variable rate limiter and the commanded load control block generally prevent the turbine from shedding load and operating below the load floor once the flag is received.

Abstract: A grid frequency rate limiting system for a droop governor is disclosed, the grid frequency rate limiting system including: a rate limit calculator for: obtaining data including at least one of: a transient power response requirement indicator, a turbo-generator power level indicator, a grid stability indicator, a fuel transfer indicator, a combustion mode timing indicator, or a temperature matching indicator; and defining rate limits according to the obtained data; a rate limiter operably connected to the rate limit calculator, the rate limiter for: obtaining a grid frequency reading associated with a grid frequency of an electrical grid; obtaining the defined rate limits; and filtering the grid frequency using the defined rate limits to provide a filtered frequency; and a droop governor operably connected to the grid frequency rate limiting system, the droop governor for: obtaining the filtered frequency; and providing a power response to the electrical grid based upon the filtered frequency.

Abstract: A system includes a controller configured to control one or more parameters of a gas turbine engine based on a feedback and a predicted lifespan of one or more components of the gas turbine engine to substantially maintain at least one of power output or heat rate above a threshold level in response to degradation or fouling of the gas turbine engine.

Abstract: Methods and systems for detecting an oscillatory event are provided. According to one embodiment, a system may include a controller configured to provide a command signal to a positioning device and a processor communicatively coupled to the controller. The command signal may include a reference position. The processor may be configured to monitor a feedback signal responsive to the command signal. The feedback signal may include an actual position of the positioning device. The processor may be further configured to determine that within a predetermined period of time the actual position is both above a predetermined upper threshold and below a predetermined lower threshold. Based on the determination, the processor may declare the oscillatory event.

Abstract: Methods and systems for detecting an oscillation error are provided. According to one embodiment, a system may include a controller, and a processor communicatively coupled to the controller. The processor may be configured to detect an oscillatory event and increment a delay timer based on a duration of the oscillatory event. The delay timer may be set to a predetermined delay value. Additionally, the processor may be configured to determine that the delay timer exceeds the predetermined delay value and, based on the determination, declare the oscillation error.

Abstract: A load protection system for a turbine is provided. The turbine has a load floor representing a lowest allowable load the turbine generally operates above. The turbine supplies power to an electrical grid. The grid has a grid frequency where as the grid frequency increases the turbine sheds load. The load protection system includes a controller in communication with the turbine and the electrical grid. The controller has a memory for storing a commanded target turbine load. The commanded target turbine load is the load the turbine operates at the load floor. The controller includes control logic for sending a flag to a variable rate limiter and a commanded load control block. The variable rate limiter and the commanded load control block generally prevent the turbine from shedding load and operating below the load floor once the flag is received.

Abstract: A grid frequency rate limiting system for a droop governor is disclosed, the grid frequency rate limiting system including: a rate limit calculator for: obtaining data including at least one of: a transient power response requirement indicator, a turbo-generator power level indicator, a grid stability indicator, a fuel transfer indicator, a combustion mode timing indicator, or a temperature matching indicator; and defining rate limits according to the obtained data; a rate limiter operably connected to the rate limit calculator, the rate limiter for: obtaining a grid frequency reading associated with a grid frequency of an electrical grid; obtaining the defined rate limits; and filtering the grid frequency using the defined rate limits to provide a filtered frequency; and a droop governor operably connected to the grid frequency rate limiting system, the droop governor for: obtaining the filtered frequency; and providing a power response to the electrical grid based upon the filtered frequency.