An automated control loop for dynamically adjusting a temperature of wet steam is provided. This leads to increased heat transfer and decreased fouling in a reboiler of a distillation column used for distilling a petrochemical. The control loop includes controlling the combining of condensed water with dry steam to produce the wet steam. The produced wet steam is input to the reboiler in order to transfer heat to the petrochemical while being converted to the condensed water. The control loop further includes monitoring a pressure of the produced wet steam, and setting a target temperature for the produced wet steam based on the monitored pressure. In addition, the control loop includes monitoring the temperature of the produced wet steam, and adjusting a proportion of the condensed water in the produced wet steam in response to the monitored temperature deviating from the set target temperature by at least a threshold value.

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 steam generator system configured to burn hydrogen and oxygen at stoichiometry along with a increased-pressure water and steam. Said steam generator system comprise a hydrogen source, an oxygen source, a nitrogen source, a water source, a steam source, a hydrogen-oxygen handling unit, a cooling unit, a one or more H2-O2 steam generators and a control unit. Said steam generator system is configured to provide said hydrogen source to said hydrogen-oxygen handling unit through an oxygen passage, said oxygen source to said hydrogen-oxygen handling unit through a hydrogen passage, and said nitrogen source to selectively purge said oxygen passage and said hydrogen passage. Said water source provide water to said cooling unit. Said cooling unit is configured to receive said water source and said steam source.

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.

Disclosed herein are a spray nozzle for an attemperator and an attemperator including the spray nozzle. An attemperator according to an embodiment includes: a steam transfer pipe through which steam is transferred; a fixed pipe which is fixed to an outer surface of the steam transfer pipe; and a spray nozzle, which is coupled to the fixed pipe, disposed in the steam transfer pipe and configured to spray cooling water into the steam transfer pipe. The spray nozzle includes, on an outer circumferential surface thereof, at least one support that protrudes toward the fixed pipe. The spray nozzle is spaced apart from the fixed pipe.

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 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).

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).

A nozzle assembly for spraying cooling fluid in a steam-desuperheating device, includes: a nozzle body; a plug element movably attached to the nozzle body; and a splitter member fixed to a front face of the plug element. The splitter member has at least one splitter arm extending across the flow passage formed in the nozzle body as viewed from the front of the plug element to deflect flow of fluid sprayed through the flow passage.