General Electric Company

John Lawrence Meyer

Mert Geveci

Cody Joe Bushey

Dean Alexander Baker

Carl Raymond Toth

Carl R Toth

Embodiments of the present disclosure include a method for controlling a power generation system, the method including: calculating, during operation of the power generation system, a target water level within a pressure vessel of the power generation system, the pressure vessel receiving a feedwater input and generating a steam output; calculating a flow rate change of the steam output from the pressure vessel; calibrating the target water level within the pressure vessel based on the output from mass flux through the pressure vessel, the mass flux through the pressure vessel being derived from the at least the feedwater input and the steam output; and adjusting an operating parameter of the power generation system based on the calibrated target water level within the pressure vessel.

Control of power generation system with water level calibration for pressure vessel

A control system for a power plant includes a sensor that measures a rotor surface temperature of a steam turbine rotor, where the temperature is a function of exhaust gasses from a heat source for heating steam to a target temperature. The control system includes a controller coupled to the sensor and configured to compute the target temperature using an inverse process model for steam turbine rotor stress dynamics, and based on a reference steam turbine rotor stress and a feedback steam turbine rotor stress, compute a measured steam turbine rotor stress based on a measured surface temperature of the steam turbine rotor, compute an estimated steam turbine rotor stress using a process model for the steam turbine rotor stress dynamics, and based on the target temperature, and compute the feedback steam turbine rotor stress based on the measured steam turbine rotor stress and the estimated steam turbine rotor stress.

Control system for managing steam turbine rotor stress and method of use

Certain embodiments of the disclosure may include systems and methods for boundary control during steam turbine acceleration. According to an example embodiment, the method can include receiving an indication the turbine is in an initial acceleration phase; receiving speed control parameter data from a plurality of sensors; receiving boundary control parameter data from a plurality of sensors; providing a control valve configured for controlling steam flow entering the turbine; determining the control valve position based on received speed control parameter data; determining the control valve position based on received boundary control parameter data; adjusting at least one boundary control parameter to the at least one boundary control parameter limit during turbine startup, wherein the value of a speed control parameter is simultaneously adjusted based on the adjusted at least one boundary control parameter; and adjusting the control valve position based at least on determined parameter data.

Growing community of inventors

Schenectady, NY, United States of America

John Lawrence Meyer