A method for operating a power plant, having at least one gas turbine engine and at least one fuel gas compressor, includes supplying fuel gas through a utility supply line, compressing the fuel gas to a plant supply pressure in the operating fuel gas compressor, and supplying the compressed fuel gas to a plant supply line. The gas turbine engine is operated at a set power output according to a power demand signal. If a failure of an operating fuel gas compressor is detected, the power output of the gas turbine engine is reduced to an emergency power output (which is lower than the set power output), and the power output of the gas turbine engine is restricted to the emergency power output. The reduction of the power output is performed in one single step and is controlled by at least one feedforward control signal.

A gas turbine engine has a compressor section and a turbine section. A secondary cooling air includes a first fluid connection to tap cooling air and pass the cooling air through a plurality of tubes, and a second fluid connection for returning air from the tubes back to at least one of the compressor and turbine for cooling. A sensor senses a condition of the cooling air downstream of the tubes and a control compares the sensed condition of the cooling air to an expected condition, and to identify a potential concern in the cooling air system should the sensed condition differ from the expected condition by more than a predetermined amount.

A device for temporarily increasing power in order to increase the power from at least one first turbine engine and from at least one second turbine engine, the device including a tank of coolant liquid, a first injection circuit connected to the tank and leading to at least one injection nozzle configured to be installed upstream from the first turbine engine, a second injection circuit connected to the tank and leading to at least one injection nozzle configured to be installed upstream from the second turbine engine, each of the first and second injection circuits including at least one first valve and at least one second valve arranged upstream from said at least one first valve, and a bridge pipe connecting together the first injection circuit and the second injection circuit upstream from their respective first valves and downstream from their respective second valves.

An operational support device sets an execution time of overfiring serving as an operation of a power generation facility at an output higher than a rated output. The device includes a life index value acquisition unit that acquires a life index value at a start time, the life index value being an index indicating a life of the power generation facility and changing in value in one direction with the output of the power generation facility; an output pattern setting unit that sets an output pattern per unit time of the power generation facility from the start time to a stop time based on the life index value such that the life index value reaches a predetermined value; and an overfiring setting unit that sets, based on the output pattern, a time in a period from the start to the stop time at which the overfiring is to be performed.

A flexible coordinated control method adapted to a thermal power unit in a deep peak-regulating operation includes: adding a reverse compensation channel from a fuel quantity instruction to a power generation load instruction on a basis of a traditional coordinated control system of a boiler-following mode; meanwhile, constructing a flexible factor by using a main steam flow quantity signal, and correcting a gain of the reverse compensation channel by the flexible factor in a product mode to obtain a reverse power generation load instruction bias value; and correcting the power generation load instruction of the unit by using the reverse power generation load instruction bias value, so as to give priority to guaranteeing the control quality of a power generation load and a throttle pressure before a steam turbine under conventional load conditions and give priority to guaranteeing the combustion stability under deep peak-regulating conditions.

A method for controlling a turbomachine including a temporary power-increasing device, the control method including a step wherein the flow rate of the coolant injected is adjusted as a function of the atmospheric pressure and/or of the ambient temperature and/or of at least one parameter such as the speed of rotation of a gas generator, the speed of rotation of a low-pressure turbine or of a power turbine, the gas pressure at the outlet of a compressor stage, the temperature at the inlet of the low-pressure turbine or of the power turbine, the engine torque, and/or the collective pitch of a helicopter rotor or the pitch of a propeller of a turboprop.

A turbine system includes a compressor section, an inlet cooling system coupled upstream of the compressor section and configured to cool ambient air entering the compressor section, and a turbine section coupled in flow communication with the compressor section and including at least one hot gas path component. The system further includes a controller configured to receive feedback parameters indicative of a temperature of the at least one hot gas path component, estimate a remaining life of the at least one hot gas path component based on the received feedback parameters, determine a desired power output of the turbine system based on the estimated remaining life of the at least one hot gas path component and a cooling capacity of the inlet cooling system, and control operation of the turbine system to cause the turbine system to generate the desired power output.

A method for operating a gas turbine at a desired gas turbine production value. The method includes setting a desired gas turbine production value based on a schedule of a reference gas turbine shaft speed with respect to ambient temperature and an exhaust temperature; comparing values of a gas turbine shaft speed to the reference gas turbine shaft speed to determine whether a difference between the gas turbine shaft speed and the reference gas turbine shaft speed is within or outside of a predetermined range; and in response to the difference being outside of the predetermined range, initiating a change in gas turbine shaft speed to cause the gas turbine to operate approximately at the desired gas turbine production value.

Embodiments of the disclosure provide a method for operating a combined cycle power plant (CCPP). The method may include generating a power plant model for operating the CCPP, determining whether at least two gas turbines in the power plant model generate a power output, and modeling a fuel consumption of the CCPP for a baseline split ratio between the at least two gas turbines. The method may also include determining whether the variant split ratio meets a quality threshold for the CCPP, and adjusting the CCPP to use the variant split ratio in response to the variant split ratio meeting the quality threshold.

A compressed air energy storage system is described, including a compressor fluidly coupled to a compressed air reservoir and an expansion train including at least a first turbine. The system further includes an electric machine aggregate configured: for converting electric power into mechanical power and driving the compressor therewith during the energy storing mode; and for converting mechanical power produced by the expansion train into electric power during the power production mode. A combustor is configured for receiving fuel and compressed air and producing combustion gas, and for supplying the combustion gas to the first turbine.