A system for controlling a boiler apparatus in a power plant to combust under optimized conditions, and a method for optimizing combustion of the boiler apparatus using the same are provided. The boiler control system may include a modeler configured to create a boiler combustion model, an optimizer configured to receive the boiler combustion model from the modeler and perform the combustion optimization operation for the boiler using the boiler combustion model to calculate an optimum control value, and an output controller configured to receive the optimum control value from the optimizer, and control an operation of the boiler by reflecting the optimum control value to a boiler control logic.

Systems and methods for generating electrical power in an organic Rankine cycle (ORC) operation include one or more heat exchangers incorporated into mobile heat generation units, and which will receive a heated fluid flow from one or more heat sources, and transfer heat therefrom to a working fluid that is circulated through an ORC unit for generation of power. In embodiments, the mobile heat generation units comprise pre-packaged modules with one or more heat exchangers connected to a pump of a recirculation system, including an array of piping, such that each mobile heat generation unit can be transported to the site and installed as a substantially stand-alone module or heat generation assembly.

A control method for operating a heat recovery steam generator having a flue gas channel in which an evaporator, having at least two evaporator heating surfaces arranged successively in the flue gas channel and at least one intermediate heating surface arranged between the evaporator heating surfaces, is provided, the method including determining a characteristic value characteristic of the heat absorption in the evaporator for the evaporator heating surfaces, additionally determining for the at least one intermediate heating surface, an additional characteristic value for the heat absorption of the intermediate heating surface, and subtracting this additional characteristic value from the characteristic value characteristic of the heat absorption in the evaporator.

The present application provides a method of adjusting a feedwater mass flow rate to maintain a constant steam temperature in an evaporator section. The method may include the steps of determining a change in a number of operational parameters, predicting a change in steam temperature based on the number of operational parameters, combining the predicted changes in steam temperature, determining a feedforward signal based on dynamically offsetting the combined predicted changes in steam temperature, and changing the mass flow rate of feedwater based on the feedforward signal.

A technique for determining a boiler water condition includes a boiler controller (aka PSE unit) having a signal processor that implements a boiler control algorithm to receive signaling containing information about sets of N consecutive probe data samples related to a boiler water condition; determine stable average signaling containing information about a stable average by averaging a set of N consecutive probe data samples in the signaling received; determine present stable average signaling containing information about a present stable average by averaging a present set of N consecutive probe data samples in the signaling received; and determine corresponding signaling containing information about the boiler water condition, based upon whether the present stable average is within an allowable limit and a comparison of the present and previous stable average signaling determined.

A technique for determining a boiler water condition includes a boiler controller (aka PSE unit) having a signal processor that implements a boiler control algorithm to receive signaling containing information about sets of N consecutive probe data samples related to a boiler water condition; determine stable average signaling containing information about a stable average by averaging a set of N consecutive probe data samples in the signaling received; determine present stable average signaling containing information about a present stable average by averaging a present set of N consecutive probe data samples in the signaling received; and determine corresponding signaling containing information about the boiler water condition, based upon whether the present stable average is within an allowable limit and a comparison of the present and previous stable average signaling determined.

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.

A method for controlling a coal supply quantity during a transient load-varying process considering exergy storage correction of a boiler system of a coal-fired unit is provided. Temperatures and pressures of working fluid and metal heating surface of the boiler system of the coal-fired unit are measured and recorded in real-time, and converted into the exergy storage amount at different operating load points. During the transient operation process, the real-time exergy storage amount of the boiler system is compared with the exergy storage amount at the corresponding steady-state load point, and the real-time exergy storage variation is obtained; thereafter, the feed-forward control signal of coal supply quantity input is superposed to the existing coal supply quantity command of the boiler system, and the coal supply quantity signal of the boiler system based on the exergy storage correction is finally generated.

A method for controlling a coal supply quantity during a transient load-varying process considering exergy storage correction of a boiler system of a coal-fired unit is provided. Temperatures and pressures of working fluid and metal heating surface of the boiler system of the coal-fired unit are measured and recorded in real-time, and converted into the exergy storage amount at different operating load points. During the transient operation process, the real-time exergy storage amount of the boiler system is compared with the exergy storage amount at the corresponding steady-state load point, and the real-time exergy storage variation is obtained; thereafter, the feed-forward control signal of coal supply quantity input is superposed to the existing coal supply quantity command of the boiler system, and the coal supply quantity signal of the boiler system based on the exergy storage correction is finally generated.

Disclosed are a test loop for simulating a steam generator with or without an axial economizer and a test method thereof. The loop includes a cooling water loop, a water supply loop, a recirculated water loop and a power supply. The cooling water loop is used for condensing and cooling wet steam and providing the wet steam to the water supply loop and the recirculated water loop. The water supply loop is used for providing cold-state water supply for a test device, the recirculated water loop is used for reheating cooled water to be saturated and providing the water to the test device. The power supply is used for supplying power to heating equipment and an electric heater in the test device. The present disclosure provides a test method of the loop. Simulation tests can be carried out on a steam generator with or without an axial economizer.