Abstract: In accordance with one aspect of the present technique a method includes receiving at least one of a speed and an acceleration of a rotating component in a rotating machine. The method includes determining whether at least one of the speed and the acceleration of the rotating component exceeds a non-trip operating (NTO) space in a speed-acceleration plane, wherein the NTO space is based on a trip overshoot model. The method further includes sending a notification for tripping the rotating machine in response to determining that at least one of the speed and the acceleration of the rotating component exceeds the NTO space.

Abstract: A method of controlling purge flow in a gas turbomachine system includes detecting a fault condition in the gas turbomachine system, initiating a shutdown of the gas turbomachine system, introducing a purge flow into a gas turbine portion of the gas turbomachine system, categorizing the fault condition as one of a category one fault and a category two fault, and validating the purge flow if the fault condition is a category one fault and invalidating the purge flow if the fault condition is a category two fault.

Abstract: Embodiments of the disclosure relate to systems and methods for controlling a gas turbine. In one embodiment, a method can be provided. Measurement data associated with the operation of a gas turbine may be received to determine if the current operating state of the gas turbine is associated with a predefined risk. Thereafter, the measurement data and one or more model operating parameters for operation of the inlet bleed heat system that minimizes the risk may be identified in order to generate one or more control signals operable to adjust the operation of the inlet bleed heat system for the gas turbine to adjust the one or more model operating parameters.

Abstract: A heat recovery steam generation system is provided. The heat recovery steam generation system includes at least one superheater in a steam path for receiving a steam flow and configured to produce a superheated steam flow. The system also includes an inter-stage attemperator for injecting an attemperation fluid into the steam path. The system further includes a control valve coupled to the inter-stage attemperator. The control valve is configured to control flow of attemperation fluid to the inter stage attemperator. The system also includes a controller coupled to the control valve and the inter-stage attemperator. The controller further includes a feedforward controller and a trimming feedback controller.

Abstract: A method of operating a process facility and a power plant operating system are provided. The power plant operating system includes a control system used by a plurality of operators and a computer device coupled to the control system. The computer device includes a processor and a memory coupled to the processor. The memory includes processor-executable instructions that, when executed by the processor, cause the computer device to perform the steps of collecting data pertaining to the operation of the power plant by each of the plurality of operators, determining an operating efficiency of each of the plurality of operators in operating the power plant, and transmitting one or more advisory messages to at least one of the plurality of operators recommending a manual intervention by the operator to operate the power plant based on the collected data and the determination of the efficiency of each of the operators.

Abstract: Systems and methods for providing stepping actuations in a power generation unit are disclosed. Certain embodiments herein may relate to manipulating actuators to produce a desired output in a power generation unit without disrupting production by the power generation output, such as megawatt and/or steam production. A model may be generated that includes one or more inputs and associated outputs in a power generation unit. The model may be leveraged to determine an actuator to adjust to create a desired output, as well as one or more different actuators to adjust to offset an otherwise negative impact on power generation unit production while maintaining the desired output.

Abstract: A system and method in a combined cycle power plant includes a processor modeling plant level performance by considering the interrelation between outputs of the gas turbine and the steam turbine. The model can be computational, predictive, or both. The model may be used to control subsystems of the plant (including the gas turbine and the steam turbine) to achieve a target plant performance. The model may also be used to diagnose or maintain subsystems of the combined cycle power plant.

Abstract: A system to performance tune a site system includes one or more controllers each controlling a subsystem of the site system by changing values of a set of parameters. The system also includes a site reference model configured to indicate a target performance of the site system, and a processor configured to instruct the one or more controllers based on the target performance for the site system.

Abstract: Compensation is provided for a fuel demand signal of a gas turbine controller during transition between operating modes. The compensation adjusts fuel demand to account for combustion efficiency differences between the starting and ending operating mode that otherwise can lead to severe swings in combustion reference temperature and lean blowout.

Abstract: A pressure control valve replication method in a gas turbine can include controlling a fuel flow to a combustion system through a gas control valve, wherein the fuel flow experiences fuel flow changes, adjusting the fuel flow through the gas control valve in response to fuel flow changes in the gas turbine and in response to pressure fluctuations in the gas turbine fuel, replicating a speed ratio valve to control pressure of the fuel flow to the gas control valve.

Abstract: Compensation is provided for a fuel demand signal of a gas turbine controller during transition between operating modes. The compensation adjusts fuel demand to account for combustion efficiency differences between the starting and ending operating mode that otherwise can lead to severe swings in combustion reference temperature and lean blowout.

Abstract: A heat recovery steam generation system is provided. The heat recovery steam generation system includes at least one superheater in a steam path for receiving a steam flow and configured to produce a superheated steam flow. The system also includes an inter-stage attemperator for injecting an attemperation fluid into the steam path. The system further includes a control valve coupled to the inter-stage attemperator. The control valve is configured to control flow of attemperation fluid to the inter stage attemperator. The system also includes a controller coupled to the control valve and the inter-stage attemperator. The controller further includes a feedforward controller and a trimming feedback controller.