General Electric Company

Other

Bryan Edward Sweet

Scott William Szepek

Michael John Mariani

Jonathan Carl Thatcher

Brian Michael Gallagher

Ravi Praveen S Eluripati

Yuhui Chen

Priscilla Childers

Timothy Robert Collins

Lauren Jeanne Buchalter

Douglas Scott Byrd

Karl Dean Minto

Dean Matthew Erickson

Justin Varkey John

David August Snider

John Rogers Huey

Thomas Edward Wickert

Korey Frederic Rendo

Darrin Glen Kirchhof

David Andrew Stats

Bret Stephen Dalton

Christina Renee Pompey

Scott Edward Sherman

Christian-Anghel Solacolu

Pramod Kumar Yadav

Daniel Joseph Peczka

Rajeev Kumar Verma

Melinda Stephanie Ammerman

Rushi Mahesh Amin

Vikram Srinivasa Muralidharan

Darrin Glen Kirchof

Pramodkumar Yadav

Embodiments of the disclosure provide a method for controlling a power generation system during on-line maintenance. The method includes operating the power generation system in a first maintenance mode, which causes a controller of the power generation system to disable an automated response to at least one operational fault of the power generation system; monitoring a risk parameter of the power generation system or at least one sensor within the power generation system while operating the power generation system in the first maintenance mode; and operating the power generation system in a second maintenance mode in response to detecting an override command, an elapsed time exceeding a time limit, or the monitored risk parameter exceeding a safety threshold. The second maintenance mode causes the controller of the power generation system to enable the automated response to the at least one operational fault of the power generation system.

Control of power generation system during online maintenance using multiple maintenance modes

A gas turbine engine system for detecting control sensor override includes a plurality of temperature sensors coupled to the gas turbine engine system. The temperature sensors are configured to generate a plurality of signals representative of exhaust gas temperatures of the gas turbine engine. The system includes an on-site monitoring system coupled in communication to the plurality of temperature sensors. The on-site monitoring system has a processor programmed to continuously receive the plurality of signals from the temperature sensors. In addition, the processor is programed to analyze the plurality of signals to verify the accuracy of the exhaust gas temperatures associated with the plurality of signals, and to detect a jumpered temperature sensor of the plurality of temperature sensors.

Methods and systems for detection of control sensor override

A gas turbine engine system for detecting control sensor override includes a plurality of temperature sensors coupled to the gas turbine engine system. The temperature sensors are configured to generate a plurality of signals representative of exhaust gas temperatures of the gas turbine engine. The system includes an on-site monitoring system coupled in communication to the plurality of temperature sensors. The on-site monitoring system has a processor programmed to continuously receive the plurality of signals from the temperature sensors. In addition, the processor is programmed to analyze the plurality of signals to verify the accuracy of the exhaust gas temperatures associated with the plurality of signals, and to detect a jumpered temperature sensor of the plurality of temperature sensors.

A non-transitory computer readable storage medium storing one or more processor-executable instructions wherein the one or more instructions when executed by a processor of a controller, cause acts to be performed is provided. The acts to be performed include obtaining one or more signals representative of ambient conditions and one or more operating conditions of the gas turbine engine, executing a model to predict a duration of a startup time for the gas turbine engine based on the ambient conditions and the one or more operating conditions, and causing a display to display the predicted duration of the startup time of the gas turbine engine.

System and method for predicting and enhancing power plant startup time

A method, including receiving a turbine system operating parameter. The turbine system operating parameter includes an indication of a frequency variation of an electric power system associated with the turbine system. The method includes determining a correction factor to vary the output of the turbine system according to the frequency variation, wherein the correction factor is based on a droop power response and a nominal droop power ratio. The droop power response is calculated based on a gas turbine power output and a speed-load error. The method further includes varying the output of the turbine system based at least in part on the correction factor.

Correction system and method for gas turbine proportional droop governor

A method of operating a fuel heating system is provided. The method includes performing pre-ignition diagnostic checks on a plurality of components of the fuel heating system, wherein at least one inlet damper and at least one outlet damper of an exhaust flow circuit are each in a closed position. The method also includes purging the fuel heating system of unburned hydrocarbons. The method further includes operating the fuel heating system in a normal operating condition. The method yet further includes operating the fuel heating system in a cool down condition, wherein the at least one inlet damper is in the closed position.

Method of operating a fuel heating system

According to one embodiment of the disclosure, a system for accelerating droop response in a combined cycle power plant may include a controller and a processor communicatively coupled to the controller. The processor may be configured to receive frequency variation data associated with a frequency variation of an electrical grid, determine, based at least in part on the frequency variation data, a target operational level of the combined cycle power plant and the droop response associated with the target operational level, calculate a variable compensation value, and apply the variable compensation value to the droop response until the target operational level is reached.

Systems and methods for accelerating droop response to frequency variation of an electrical grid in a combined cycle power plant

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.

Methods and systems for detecting an oscillation error

A system and method to reduce the gas fuel supply pressure requirements of a gas turbine, which results in an increased operability range and a reduction in gas turbine trips. According to the method, the gas turbine is allowed to start and operate at supply pressures determined as a function of ambient conditions and gas turbine compressor pressure ratio. This increases the operability window, and reduces or eliminates the need for gas fuel compressors.

Pressure control method and system to reduce gas turbine fuel supply pressure requirements

A method detection of leakage through at least one first valve includes admitting an amount of fluid into a first control volume in operable communication with the at least one first valve, thereby pressurizing the first control volume. The first control volume is isolated and a rate of change of pressure in a second control volume in operable communication with the at least one first valve is measured. A system for detecting leakage across at least one first valve includes a first control volume receptive of an amount of fluid and a second control volume in flow communication with the first control volume. At least one first valve is located between the first control volume and the second control volume, and a rate of change in pressure in the second control volume indicates a rate of leakage through the at least one first valve.

Method and system for fluid valve leak detection

Methods and systems for operating a gas turbine engine system are provided. The system includes a gas turbine engine that includes at least one combustor configured to receive a flow of fuel from a flow control device and a fuel control system. The fuel control system includes a piping system configured to channel the flow of fuel from a fuel source to the flow control device, a sensor configured to generate a signal indicative of a property of the flow of fuel wherein the property of the flow of fuel is variable over time, and a controller including a processor. The processor is programmed to receive the generated signal, using a flow model of the piping system and the received signal, iteratively track the progress of a plurality of discrete volumes flowing through the piping system, and control the flow of fuel using the flow control devices.

Method and system for operating gas turbine engine systems

Methods and systems for operating a gas turbine engine system are provided. The system includes a fuel control system. The fuel control system includes a plurality of sensors positioned about the gas turbine engine system and configured to measure at least one parameter associated with the sensor, and a processor programmed to receive a signal from at least one of the plurality of sensors indicative of a composition of the fuel. The processor is further programmed to determine the physical properties of a fuel at an inlet to the flow control devices using a flow model and the at least one signal, determine a corresponding correction to a gas fuel flow gain using the determined physical properties, and automatically control fuel delivery as well as fuel split between the fuel injection points on the combustor using the adjusted flow gain to facilitate permitting a relatively large variation in the fuel composition for use in the gas turbine engine.

Methods and apparatus for operating gas turbine engine systems

Block loading may occur during the process of restoring an electrical grid after a blackout. A method and system for coordinating the loading of a combined cycle power plant to support block loading is provided. The power plant may include a gas turbine and a steam turbine. The method and system may provide load control loops, for the gas and steam turbine, which support block loading.

Method and system for power plant block loading

Pressure control method to reduce gas turbine fuel supply pressure requirements

A method is provided for controlling variable inlet and stator vanes of a heavy-duty gas turbine electrical power generator compressor component upon occurrence of power grid under-frequency events. Variable inlet guide vanes and the front four variable stator vanes of the compressor are ganged together by means of a common actuation mechanism. Altering the angle of the ganged vanes changes the overall airflow consumption of the compressor and affects the amount of turbine output power produced. Predetermined operational schedules for varying the angular position of the stator vanes in accordance with compressor speed are defined for both nominal and under-frequency operating conditions to ensure optimum compressor efficiency without violating minimum safe compressor surge margin criteria. During a power grid under-frequency event, the variable stator vanes of the compressor are operated in a manner that provides a smooth transition from the predetermined nominal operational schedule to the predetermined under-frequency operational schedule.

Method and operational strategy for controlling variable stator vanes of a gas turbine power generator compressor component during under-frequency events

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Valatie, NY, United States of America

Bryan Edward Sweet