General Electric Company

Other

Scott William Szepek

Sreedhar Desabhatla

Bryan Edward Sweet

Justin Varkey John

Michael John Mariani

Daniel Joseph Peczka

Lauren Jeanne Buchalter

Karl Dean Minto

William Forrester Seely

Nirm Velumylum Nirmalan

Ara Panosyan

Mustafa Tekin Dokucu

Michael Joseph Alexander

Frederick William Block

Warren James Mick

John Charles Intile

Naresh Acharya

John Rogers Huey

Luca Parolini

Daniel Richard Waugh

David Andrew Stats

John Joseph Raffensperger

Maxime Buquet

Louis Veltre

Yuhui Chen

Krishna Kumar Anaparthi

Adolfo Anta Martinez

Bradley Steven Carey

Alexis Sesmat

John Michael Undrill

Robert Loeven

This application provides methods and systems for rapid load support for grid frequency transient events. Example electric power systems may include a turbine, a generator coupled to the turbine, where the generator is configured to provide power to an electrical grid, and a controller configured to detect a grid event, determine a rate of change of frequency (rate of change of frequency) value, determine a predicted post-grid event governor set point based on the rate of change of frequency value, and initiate a change to at least one turbine operating parameter based on the predicted post-grid event governor set point.

Systems and methods for improved rate of change of frequency ride-through in electric power systems

An electric power system includes a generating unit, which includes a controller for controlling an operational mode of the generating unit. The electric power system also includes an event estimator communicatively coupled to the controller of the generating unit and a network estimator communicatively coupled to the event estimator. The network estimator includes a processor configured to receive status information associated with the electric power system, determine, based upon the status information, at least one characteristic of the electric power system, and transmit the at least one characteristic to the event estimator.

Systems and methods for high rate-of-change-of-frequency ride-through in electric power systems

A system includes a model-based control system configured to receive data relating to parameters of a machinery via a plurality of sensors coupled to the machinery and select one or more models configured to generate a desired parameter of the machinery based on a determined relationship between the parameters and the desired parameter. The one or more models represent a performance of a device of the machinery. The model-based control system is configured to generate the desired parameter using the data and the one or more models control a plurality of actuators coupled to the machinery based on the desired parameter. Further, the model-based control system is configured to empirically tune the one or more models based on the data, the one or more parameters, and the desired parameter, compare the empirical tuning to a baseline tuning, and determine an operational state of the device based on the comparison.

Asset degradation model baselinening system and method

The disclosure relates to optimization of gas turbine power plant response during power system transients. In certain embodiments, systems, methods, and apparatus can control a power generating system by using the reactive components of the current and the reactive components of the voltage and the magnitude of the voltage at the generator terminals of a gas turbine generator system. In one embodiment, a system can identify a power system fault based on at least three conditions occurring for a specified duration and at substantially the same time: (1) an increase in the reactive current, (2) a decrease in the magnitude of the voltage, and (3) an increase in the reactive power. In one embodiment, a power system can further detect a remote breaker open (RBO) condition, and distinguish a RBO condition from a power system fault condition.

Systems and methods for controlling a power generation system

A method may involve monitoring a first set of electrical properties associated with an electrical grid configured to couple to a generator and determining whether a transient event is present on the electrical grid based on the first set of electrical properties. The method may also involve determining a mechanical power present on a shaft of the generator based on a second set of electrical properties associated with the generator, the electrical grid, or both when the transient event is present and sending the mechanical power to a controller associated with a turbine configured to couple to the generator, wherein the controller is configured to adjust one or more operations of the turbine based on the mechanical power.

Systems and methods for adjusting operations of a gas turbine following a transient event

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

Certain embodiments of the disclosure may include systems, methods and apparatus for operating and validating a compressor. According to an example embodiment of the disclosure, a method is provided for validating compressor operation. The method can include receiving compressor operating parameter data from a plurality of sensors; and adjusting a portion of a variable flow area downstream of a compressor discharge to achieve a desired compressor pressure ratio.

Systems and methods for operating and validating a compressor

Certain embodiments of the invention may include systems, methods, and apparatus for detecting failure in gas turbine hardware. According to an example embodiment of the invention, a method for detecting a failure in a gas turbine is provided. The method can include monitoring a parameter associated with the turbine, wherein the monitored parameter comprises at least one turbine bucket temperature, detecting an event associated with operation of the turbine, wherein the event is based at least in part on the monitored parameter, and initiating shutdown of the turbine upon detection of the event wherein the monitored parameter is above a predetermined value for at least a predetermined time duration.

Systems, methods, and apparatus for detecting failure in gas turbine hardware

Certain embodiments of the invention may include systems and methods for providing unchoked control of gas turbine fuel control valves. According to an exemplary embodiment of the invention, a method is provided for active control of a gas flow control valve. The method may include receiving a desired fuel command and an inlet pressure parameter, and determining a gas flow gain based at least in part on the inlet pressure parameter. The method may also include determining a valve flow coefficient based at least in part on the desired fuel command and the gas flow gain, and controlling the gas flow control valve based at least in part on the valve flow coefficient.

Systems and methods for unchoked control of gas turbine fuel gas control valves

Certain embodiments of the invention may include systems, methods, and apparatus for determining steady state conditions in a gas turbine. According to an example embodiment of the invention, a method for determining stability in a gas turbine is provided. The method can include receiving a guide vane (VGV) command and a fuel stroke reference (FSR) command associated with a gas turbine control system, determining a filtered VGV change based at least in part on the received VGV command, determining a filtered FSR change based at least in part on the received FSR command, and outputting a unit stability signal after a pickup delay time when the filtered VGV change is less than a predetermined VGV stability threshold and the filtered FSR change is less than a predetermined FSR stability threshold.

Systems, methods, and apparatus for determining steady state conditions in a gas turbine

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

A method for transient fuel control for fuel delivery circuits for a plurality of connected gas turbines, the method includes: detecting a transient grid event based on an indication of at least one of a rapid change in a fuel command to the gas turbine or an acceleration of the turbine shaft; upon detection of the transient grid event, commanding a gas turbine controller to transfer the gas turbine to at least one intermediate load; adjusting a fuel split to maintain combustor stability during the transient grid event, and using a predetermined island load demand signal to apportion an island load demand among the connected gas turbine generators.

Growing community of inventors

Schenectady, NY, United States of America

Scott William Szepek