Disclosed is a method for setting parameters of a load feedforward controller for superheated steam temperature control, which belongs to the technical field of thermal automatic control. This method adds a load feedforward controller to the conventional boiler superheated steam temperature spray desuperheating cascade control system. The application provides a structure of the load feedforward controller, and a method for designing the parameters of the load feedforward controller according to the dynamic characteristics of the superheated steam temperature related to feed coal flow disturbance, feedwater flow disturbance and desuperheating water spray disturbance. The method of the application could effectively reduce the superheated steam temperature deviation in the process of unit load rise or drop, and the design method is simple, effective and easy to realize in engineering.

Disclosed is a method for setting parameters of a load feedforward controller for superheated steam temperature control, which belongs to the technical field of thermal automatic control. This method adds a load feedforward controller to the conventional boiler superheated steam temperature spray desuperheating cascade control system. The application provides a structure of the load feedforward controller, and a method for designing the parameters of the load feedforward controller according to the dynamic characteristics of the superheated steam temperature related to feed coal flow disturbance, feedwater flow disturbance and desuperheating water spray disturbance. The method of the application could effectively reduce the superheated steam temperature deviation in the process of unit load rise or drop, and the design method is simple, effective and easy to realize in engineering.

A gas turbine exhaust heat recovery plant includes a plurality of gas turbine exhaust heat recovery devices that have a gas turbine and an exhaust heat recovery boiler for generating steam by recovering exhaust heat of the gas turbine, a steam-utilizing facility that utilizes the steam generated by the exhaust heat recovery boiler, and an inter-device heat medium supply unit capable of supplying a portion of water heated or a portion of the steam generated by at least one of the gas turbine exhaust heat recovery devices out of the plurality of gas turbine exhaust heat recovery devices, to the other gas turbine exhaust heat recovery device.

Processing contaminated water containing volatile or/and semi-volatile compounds via flash evaporation. Method and system include: superheating contaminated water (via a superheating unit), for forming superheated contaminated water having a temperature equal to or higher than a predetermined threshold temperature; flash evaporating the superheated contaminated water (via a flash evaporation unit), for forming superheated contaminated steam; and thermally oxidizing the superheated contaminated steam (via a thermal oxidation unit), so as to thermally oxidize the volatile compounds contained therein, and form thermal oxidation gas/vapor products. Optionally, further includes integrated configuration and operation of a process control/data-information processing unit, and a heat recycling unit. Results in obtaining high yields and high energy efficiencies for removal of volatile compounds from contaminated water. Particularly applicable for processing water contaminated with volatile organic compounds (VOCs) or/and semi-volatile organic compounds (SVOCs), and volatile or/and semi-volatile inorganic compounds.

Processing contaminated water containing volatile or/and semi-volatile compounds via flash evaporation. Method and system include: superheating contaminated water (via a superheating unit), for forming superheated contaminated water having a temperature equal to or higher than a predetermined threshold temperature; flash evaporating the superheated contaminated water (via a flash evaporation unit), for forming superheated contaminated steam; and thermally oxidizing the superheated contaminated steam (via a thermal oxidation unit), so as to thermally oxidize the volatile compounds contained therein, and form thermal oxidation gas/vapor products. Optionally, further includes integrated configuration and operation of a process control/data-information processing unit, and a heat recycling unit. Results in obtaining high yields and high energy efficiencies for removal of volatile compounds from contaminated water. Particularly applicable for processing water contaminated with volatile organic compounds (VOCs) or/and semi-volatile organic compounds (SVOCs), and volatile or/and semi-volatile inorganic compounds.

A technique of controlling a steam generating boiler system having multiple superheater sections includes determining multiple control signals to control a temperature of output steam to a turbine. The technique uses a first control block to determine an offset value based on multiple input temperatures and a dynamic matrix control (DMC) block to determine input steam control signals based on an output temperature and an output temperature setpoint. The technique modifies one of the input steam control signals based on the offset value. The modified input steam control signal and the unmodified input steam control signal are provided to respective field devices to control the input temperatures and, as a result, the output temperature.

A technique of controlling a steam generating boiler system having multiple superheater sections includes determining multiple control signals to control a temperature of output steam to a turbine. The technique uses a first control block to determine an offset value based on multiple input temperatures and a dynamic matrix control (DMC) block to determine input steam control signals based on an output temperature and an output temperature setpoint. The technique modifies one of the input steam control signals based on the offset value. The modified input steam control signal and the unmodified input steam control signal are provided to respective field devices to control the input temperatures and, as a result, the output temperature.

A boiler is disclosed in which the furnace is divided into a lower furnace and an upper furnace. The lower furnace uses water-cooled membrane walls, while the upper furnace uses steam-cooled membrane walls that act as superheating surfaces. A steam-cooled circuit includes a steam separator, a primary superheater, and the steam-cooled membrane walls of the upper furnace. During start-up, a diversion path is opened that reduces dry steam flow through the primary superheater and increases dry steam flow through the steam-cooled membrane walls of the upper furnace. This protects the steam-cooled membrane walls from excessive thermal stresses during start-up.

A boiler is disclosed in which the furnace is divided into a lower furnace and an upper furnace. The lower furnace uses water-cooled membrane walls, while the upper furnace uses steam-cooled membrane walls that act as superheating surfaces. A steam-cooled circuit includes a steam separator, a primary superheater, and the steam-cooled membrane walls of the upper furnace. During start-up, a diversion path is opened that reduces dry steam flow through the primary superheater and increases dry steam flow through the steam-cooled membrane walls of the upper furnace. This protects the steam-cooled membrane walls from excessive thermal stresses during start-up.

A boiler is disclosed in which the furnace is divided into a lower furnace and an upper furnace. The lower furnace uses water-cooled membrane walls, while the upper furnace uses steam-cooled membrane walls that act as superheating surfaces. A transition section is present between the lower furnace and the upper furnace. The boiler is a high temperature sub-critical natural circulation boiler which is completely top supported. The lower furnace is supported through the transition section by the upper furnace.