General Electric Company

Darrin Glen Kirchhof

Norman Arnold Turnquist

Karl Dean Minto

Shorya Awtar

Frederick George Baily

Mark Edward Burnett

Fernando Javier D'Amato

Daniel Francis Holzhauer

Gordon Raymond Smith

Bryan Edward Sweet

Ramu Sharat Chandra

Christopher Eugene Long

William George Carberg

Rajeeva Kumar

Dean Alexander Baker

Nicholas Andrew Tisenchek

William Charles Below

Systems and methods for controlling exhaust steam temperatures from a finishing superheater are provided. In certain embodiments, the system includes a controller which includes control logic for predicting an exhaust temperature of steam from the finishing superheater using model-based predictive techniques (e.g., based on empirical data or thermodynamic calculations). Based on the predicted exhaust temperature of steam, the control logic may use feed-forward control techniques to control the operation of an inter-stage attemperation system upstream of the finishing superheater. The control logic may determine if attemperation is required based on whether the predicted exhaust temperature of steam from the finishing superheater exceeds a set point temperature as well as whether the inlet temperature of steam into the finishing superheater drops below a set point temperature of steam. The attemperation system may include a characterizing function to linearize the valve operation controlled by the control logic to inject cooled, high-pressure feedwater into the steam upstream of the finishing superheater, which may, in turn, control the exhaust temperature of steam from the finishing superheater. The disclosed embodiments may also be applied to any systems where an outlet temperature of a fluid from a heat transfer device may be controlled.

Inter-stage attemperation system and method

A control system for a combined cycle power generation system including a gas turbine engine (GT), a heat recovery steam generator (HRSG), and a steam turbine (ST) includes a display wherein an operator may observe information about predicted operating parameters; a user interface wherein an operator may provide additional operating constraints; and a controller configured to generate input profiles of the GT, the HRSG, and the ST that satisfy the nominal constraints and any additional constraints and to generate the information about the predicted operating parameters. The controller may be configured to detect a stage transition of power generation system operation and update the input profiles. The controller may be configured to generate alternative operating scenarios by mapping alternative control actions to an operating constraint of at least one of the system components.

System for controlling input profiles of combined cycle power generation system

Methods and apparatus for controlling load on a machine are provided. The method includes determining a maximum value of a process variable using a predictive model of the machine while holding a control output associated with the process variable substantially constant over a prediction period, incrementing the control output if the determined maximum value of the process variable is within an allowable limit range, and setting the control output to the last value of the process variable that did not cause the process value to exceed the allowable range.

Methods and apparatus for model predictive control in a real time controller

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

An actuation pressure control system effects actuation of adjustable seal segments between stationary and rotating turbomachinery members. At least one actuator is coupled with each of the adjustable seal segments and controls a position of the seal segments, respectively. A pressure system is disposed within the turbomachinery that measures or estimates ambient pressure representing an actuator back pressure acting against the actuator. A pressure regulator via a controller pressurizes the actuator to a level sufficient for a desired seal operation and controls actuator pressure based on the actuator back pressure.

Actuation pressure control for adjustable seals in turbomachinery

A method and system for determining a limit exceedance of an operating parameter in a steam turbine system. Measurement data associated with the operating parameter is received, and a limit exceedance is determined when the rate of change in the received data over a predefined period of time exceeds a predefined limit. A control action is taken when a limit exceedance has been determined.

Method for determining limit exceedance

In a method of controlling steam flow through a steam turbine having a turbine rotor, a maximum heat transfer rate is determined based on thermal stress calculations in the turbine rotor. A maximum steam flow rate can be calculated based on the maximum heat transfer rate. An actual steam flow rate through the steam turbine is determined, and a turbine inlet valve is controlled based on a difference between the actual steam flow rate and the maximum steam flow rate. In this manner, steam flow can be controlled to the steam turbine in such a way as to limit thermal stress to an acceptable level while minimizing start times and maximizing operability.

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Schenectady, NY, United States of America

Darrin Glen Kirchhof