Abstract: A system for maintaining electrical power continuity in a steam-based power plant is provided. The system includes a fossil fuel-fired power generation unit and an electrical power storage apparatus. The fossil fuel-fired power generation unit is operative to generate and provide electrical power to an electrical power grid. The electrical power storage apparatus is electrically coupled to the fossil fuel-fired power generation unit and operative to: receive and store electrical power from the fossil fuel-fired power generation unit during periods of surplus electrical power generation by the fossil fuel-fired power generation unit; and to provide electrical power to a component of the fossil fuel-fired power generation unit during periods of electrical power shortage by the electrical power grid.

Abstract: A system for maintaining electrical power continuity in a steam-based power plant is provided. The system includes a fossil fuel-fired power generation unit and an electrical power storage apparatus. The fossil fuel-fired power generation unit is operative to generate and provide electrical power to an electrical power grid. The electrical power storage apparatus is electrically coupled to the fossil fuel-fired power generation unit and operative to: receive and store electrical power from the fossil fuel-fired power generation unit during periods of surplus electrical power generation by the fossil fuel-fired power generation unit; and to provide electrical power to a component of the fossil fuel-fired power generation unit during periods of electrical power shortage by the electrical power grid.

Abstract: Method and system for adjusting a measured reheat outlet steam temperature (“RPV”) to approximate a reheat outlet steam temperature setpoint (“RSP”) in a boiler. An RPV is compared to an RSP. If the RPV is less than the RSP and a position of a fuel nozzle tilt (“TILTPV”) is below a high limit of the fuel nozzle tilt (“TILTHIGH”), the TILTPV is increased while a flow rate of a secondary flue gas recirculation (“SFGRPV”) is kept constant. If the RPV is less than the RSP and the TILTPV is at the TILTHIGH, the SFGRPV is increased. If the RPV is greater than the RSP and the SFGRPV is greater than a low limit of flow rate of the SFGR (“SFGRLOW”), the SFGRPV is decreased, while the TILTPV is kept constant. If the RPV is greater than the RSP and the SFGRPV is at the SFGRLOW, the TILTPV is decreased.

Abstract: An automatic tuning control system and method for controlling air pollution control systems such as a dry flue gas desulfurization system is described. The automatic tuning control system includes one or more PID controls and one or more supervisory MPC controller layers. The supervisory MPC controller layers are operable for control of an air pollution control system and operable for automatic tuning of the air pollution control systems using particle swarm optimization through simulation using one or more dynamic models, and through control system tuning of each of the PID controls, MPC controller layers and an integrated MPC/PID control design.

Abstract: A method for controlling at least one operational parameter of a plant (1) having a combustion unit (3) can include estimating a status of at least one operational variable of the plant to identify an estimated value for the operational variable. For each operational variable, the estimated value for the operational variable can be compared with a measured value of the operational variable to determine an uncertainty value based on a difference in value between the measured value and the estimated value for the operational variable. A control signal can be generated based on a reference signal, the measured value, and the deviation value for sending to at least one element of the plant (1) for controlling a process of the plant (1).

Abstract: A control system for optimizing a chemical looping (“CL”) plant includes a reduced order mathematical model (“ROM”) that is designed by eliminating mathematical terms that have minimal effect on the outcome. A non-linear optimizer provides various inputs to the ROM and monitors the outputs to determine the optimum inputs that are then provided to the CL plant. An estimator estimates the values of various internal state variables of the CL plant. The system has one structure adapted to control a CL plant that only provides pressure measurements in the CL loops A and B, a second structure adapted to a CL plant that provides pressure measurements and solid levels in both loops A, and B, and a third structure adapted to control a CL plant that provides full information on internal state variables. A final structure provides a neural network NMPC controller to control operation of loops A and B.

Abstract: An oxy-combustion boiler unit is disclosed which includes a furnace for combusting fuel and for emitting flue gas resulting from combustion. The furnace has first, second and third combustion zones, and an air separation unit for separating oxygen gas from air and providing a first portion of the separated oxygen to a first oxidant flow, a second portion to a second oxidant flow, and a third portion of the separated oxygen gas to the first, second, and third zones of the furnace. A controller can cause the separated oxygen gas to be distributed so that the first and second oxygen flows have a desired oxygen content, and so that the first, second, and third zones of the furnace receive a desired amount of oxygen based on a combustion zone stoichiometry control.

Abstract: Disclosed herein is a control system for NOx reduction in a power plant, the control system comprising a model predictive controller; a proportional integral differential controller and/or an adaptive controller; where the proportional integral differential controller and/or an adaptive controller are subordinated to and in operative communication with the model predictive controller; where the proportional integral differential controller and/or an adaptive controller comprise a feedback loop; a NOx reduction system comprising a NOx reducing agent supply tank and a water supply tank; and a furnace for combusting a fuel; where the furnace lies downstream of the NOx reduction system and where the furnace is provided with a plurality of nozzles that are in fluid communication with the NOx reduction system; where the control system is in electrical communication with the NOx reduction system.

Abstract: A method for controlling at least one operational parameter of a plant (1) having a combustion unit (3) can include estimating a status of at least one operational variable of the plant to identify an estimated value for the operational variable. For each operational variable, the estimated value for the operational variable can be compared with a measured value of the operational variable to determine an uncertainty value based on a difference in value between the measured value and the estimated value for the operational variable. A control signal can be generated based on a reference signal, the measured value, and the deviation value for sending to at least one element of the plant (1) for controlling a process of the plant (1).

Abstract: A plant (1) and a gas processing unit (GPU) (17) of the plant can be configured to operate in accordance with a method that is configured to permit the GPU (17) to operate such that the optimum operating point for the GPU (17) at steady state to produce liquid carbon dioxide product from a separation unit (117) of the GPU (17) for sending to a storage device (19) is achieved with a desired purity level while simultaneously maintaining a required minimum carbon capture rate with the minimum consumption of power and/or minimum economic cost associated with operations of the GPU (17). A controller (23) can be configured to communicate with elements of the GPU (17) to receive parameter values to calculate manipulated variables configured to bias set points for parameters used to control operations of different elements of the GPU (17).

Abstract: An electricity production system configured to operate in accordance with a method of operating an electricity production system that at least includes the steps of: determining an oxygen distribution between oxygen gas to be separated by an air separation unit (“ASU”) and oxygen gas stored in a storage tank of the ASU to be fed to the boiler unit, determining a carbon capture value for a gas processing unit, determining a power consumption value for the gas processing unit and the ASU, determining a total power demand value based on the power consumption value of the gas processing unit and the ASU, and on a determined electricity demand, and controlling the boiler unit, the turbine, the ASU, and the gas processing unit based on the determined total power demand along with correcting signals generated from a coordinated Model Predictive Control.

Abstract: A control system (207) for optimizing a chemical looping process of a power plant includes an optimizer (420), an income algorithm (230) and a cost algorithm (225) and a chemical looping process models. The process models are used to predict the process outputs from process input variables. Some of the process in puts and output variables are related to the income of the plant; and some others are related to the cost of the plant operations. The income algorithm (230) provides an income input to the optimizer (420) based on a plurality of input parameters (215) of the power plant. The cost algorithm (225) provides a cost input to the optimizer (420) based on a plurality of output parameters (220) of the power plant. The optimizer (420) determines an optimized operating parameter solution based on at least one of the income input and the cost input, and supplies the optimized operating parameter solution to the power plant.

Abstract: An electricity production system configured to operate in accordance with a method of operating an electricity production system that at least includes the steps of: determining an oxygen distribution between oxygen gas to be separated by an air separation unit (“ASU”) and oxygen gas stored in a storage tank of the ASU to be fed to the boiler unit, determining a carbon capture value for a gas processing unit, determining a power consumption value for the gas processing unit and the ASU, determining a total power demand value based on the power consumption value of the gas processing unit and the ASU, and on a determined electricity demand, and controlling the boiler unit, the turbine, the ASU, and the gas processing unit based on the determined total power demand along with correcting signals generated from a coordinated Model Predictive Control.

Abstract: A method of operating an electricity production system having at least one oxy-combustion boiler unit and a turbine for electricity generation at least includes the steps of: determining a power demand for an air separation unit that supplies oxygen gas to the boiler unit and a gas processing unit that treats flows of fluid for CO2 capture; determining a total power demand for electricity production that includes the determined power demand for the air separation unit and the gas processing unit; and coordinating operation of the air separation unit, gas processing unit, the boiler unit, and the turbine such that power generated by the plant provides power that meets the determined total power demand and also controls steam pressure of the turbine to a pre-specified level.

Abstract: An oxy-combustion boiler unit is disclosed which includes a furnace for combusting fuel and for emitting flue gas resulting from combustion. The furnace has first, second and third combustion zones, and an air separation unit for separating oxygen gas from air and providing a first portion of the separated oxygen to a first oxidant flow, a second portion to a second oxidant flow, and a third portion of the separated oxygen gas to the first, second, and third zones of the furnace. A controller can cause the separated oxygen gas to be distributed so that the first and second oxygen flows have a desired oxygen content, and so that the first, second, and third zones of the furnace receive a desired amount of oxygen based on a combustion zone stoichiometry control.

Abstract: An automatic tuning control system and method for controlling air pollution control systems such as a dry flue gas desulfurization system is described. The automatic tuning control system includes one or more PID controls and one or more supervisory MPC controller layers. The supervisory MPC controller layers are operable for control of an air pollution control system and operable for automatic tuning of the air pollution control systems using particle swarm optimization through simulation using one or more dynamic models, and through control system tuning of each of the PID controls, MPC controller layers and an integrated MPC/PID control design.

Abstract: A control system for optimizing a chemical loop system includes one or more sensors for measuring one or more parameters in a chemical loop. The sensors are disposed on or in a conduit positioned in the chemical loop. The sensors generate one or more data signals representative of an amount of solids in the conduit. The control system includes a data acquisition system in communication with the sensors and a controller in communication with the data acquisition system. The data acquisition system receives the data signals and the controller generates the control signals. The controller is in communication with one or more valves positioned in the chemical loop. The valves are configured to regulate a flow of the solids through the chemical loop.

Abstract: A control system for optimizing a chemical loop system includes one or more sensors for measuring one or more parameters in a chemical loop. The sensors are disposed on or in a conduit positioned in the chemical loop. The sensors generate one or more data signals representative of an amount of solids in the conduit. The control system includes a data acquisition system in communication with the sensors and a controller in communication with the data acquisition system. The data acquisition system receives the data signals and the controller generates the control signals. The controller is in communication with one or more valves positioned in the chemical loop. The valves are configured to regulate a flow of the solids through the chemical loop.

Abstract: A control system for optimizing a chemical loop system includes one or more sensors for measuring one or more parameters in a chemical loop. The sensors are disposed on or in a conduit positioned in the chemical loop. The sensors generate one or more data signals representative of an amount of solids in the conduit. The control system includes a data acquisition system in communication with the sensors and a controller in communication with the data acquisition system. The data acquisition system receives the data signals and the controller generates the control signals. The controller is in communication with one or more valves positioned in the chemical loop. The valves are configured to regulate a flow of the solids through the chemical loop.

Abstract: A system for optimizing and controlling a circulating fluidized bed combustion (FBC) system (7) and an air pollution control (APC) system (9) includes a controller (205, 305, 406) and an optimizer (210, 310). The controller (205, 305, 406) is connected to the FBC system (7) and/or the APC system (9). The optimizer (210, 310) is connected to the controller (205, 305, 406). The optimizer (210, 310) provides an optimized setpoint (220, 320, 420) to the controller (205, 305, 406) based on an economic parameter (235, 335, 435) and system outputs (230, 330) from the FBC system (7) and the APC system (9). The controller (205, 305, 406) provides an optimized input (215, 315) to the FBC system (7) and/or the APC system (9) based on the optimized setpoint (220, 320, 420) from the optimizer (210, 310) to optimize operation of the FBC system (7) and/or the APC system (9).