A smoke removal device includes a connecting tube, a burner, and a plurality of heat storage meshes. The connecting tube has an inlet end and an outlet end. The burner is disposed in the connecting tube and has a flame outlet. The heat storage meshes are sequentially disposed between the flame outlet and the outlet end. The heat storage meshes includes a first heat storage mesh and a second heat storage mesh. The first heat storage mesh is located between the second heat storage mesh and the flame outlet. A mesh-number of per unit area of the first heat storage mesh is larger than that of the second heat storage mesh. The first heat storage mesh and the second heat storage mesh could slow down a flow rate of flame to increase temperatures of the heat storage meshes. The smoke is burned off once touching the heat storage meshes.

The boiler (1) has side tubed walls (2) enclosing an inner space (3) and a device for selective non catalytic reduction (7). The device for selective non catalytic reduction (7) has a lance (8) carrying a hose (9) having at least a nozzle (10) and a hose drive mechanism (11) for driving the hose within the lance. The lance (8) protrudes into the inner space (3) from a side tubed wall (2) of the boiler (1).

An exhaust gas treatment device includes an exhaust gas line through which a combustion exhaust gas discharged from a power generation facility flows, a waste heat recovery boiler recovering waste heat of the combustion exhaust gas, a branch exhaust gas line provided to be connected between a front stage and a downstream stage of the waste heat recovery boiler on a main exhaust gas line, a nitrogen oxide removal unit removing nitrogen oxide in an integrated combustion exhaust gas into which a combustion exhaust gas flowing through the main exhaust gas line and a combustion exhaust gas flowing through the branch exhaust gas line are integrated, an integrated waste heat recovery boiler recovering waste heat of the integrated combustion exhaust gas from which nitrogen oxide has been removed, and a CO.sub.2 recovery unit recovering CO.sub.2 in the integrated combustion exhaust gas.

An integrated comprehensive adjustment method for a pulverized coal boiler based on high-temperature corrosion prevention and control of water wall is provided. The method includes: during shutdown period of the boiler, mounting reducing atmosphere sampling pipe on a water-cooled wall region; carrying out a diagnostic test on the boiler; carrying out an optimization and adjustment test of a boiler pulverizing system; carrying out a single-factor adjustment test of boiler-related parameters; determining degrees of influence of different parameters on water wall reducing atmosphere, thermal efficiency of the boiler and NO.sub.x concentration at a denitration inlet; carrying out an optimization test of ammonia spraying of a denitration system; carrying out a maximum safe denitration efficiency test; and finding a balance point among the water wall reducing atmosphere, the thermal efficiency of the boiler and the NO.sub.x concentration at the denitration inlet.

An exhaust gas treatment device includes an exhaust gas line through which a combustion exhaust gas discharged from a power generation facility flows, a waste heat recovery boiler recovering waste heat of the combustion exhaust gas, a branch exhaust gas line provided to be connected between a front stage and a downstream stage of the waste heat recovery boiler on a main exhaust gas line, a nitrogen oxide removal unit removing nitrogen oxide in an integrated combustion exhaust gas into which a combustion exhaust gas flowing through the main exhaust gas line and a combustion exhaust gas flowing through the branch exhaust gas line are integrated, an integrated waste heat recovery boiler recovering waste heat of the integrated combustion exhaust gas from which nitrogen oxide has been removed, and a CO.sub.2 recovery unit recovering CO.sub.2 in the integrated combustion exhaust gas.

A multi-functional composition of matter that is useful for injection into a flue gas stream to rapidly and efficiently remove mercury from the flue gas streams, particularly at above average flue stream temperatures of about 340° F. or higher. The multi-functional composition of matter may include a fixed carbon content of at least about 20 wt. %, a mineral content of from about 20 wt. % to about 50 wt. %, a sum of micropore plus mesopore volume of at least about 0.20 cc/g, a micropore volume to mesopore volume ratio of at least about 0.7, and a tapped density of not greater than about 0.575 g/ml. These compositions may be further characterized by number of particles per gram of the composition of matter such that the composition may have at least about 0.8 billion particles per gram, or even as many as 1.5 billion particles per gram. These physical and chemical properties may enhance (1) the oxidation reaction kinetics for the oxidation of mercury species, (2) frequency of contact events, and (3) capture and sequestration of mercury, to achieve efficient mercury capture by the composition even in high temperature flue gas streams.

A multi-functional composition of matter that is useful for injection into a flue gas stream to rapidly and efficiently remove mercury from the flue gas streams, particularly at above average flue stream temperatures of about 340° F. or higher. The multi-functional composition of matter may include a fixed carbon content of at least about 20 wt. %, a mineral content of from about 20 wt. % to about 50 wt. %, a sum of micropore plus mesopore volume of at least about 0.20 cc/g, a micropore volume to mesopore volume ratio of at least about 0.7, and a tapped density of not greater than about 0.575 g/ml. These compositions may be further characterized by number of particles per gram of the composition of matter such that the composition may have at least about 0.8 billion particles per gram, or even as many as 1.5 billion particles per gram. These physical and chemical properties may enhance (1) the oxidation reaction kinetics for the oxidation of mercury species, (2) frequency of contact events, and (3) capture and sequestration of mercury, to achieve efficient mercury capture by the composition even in high temperature flue gas streams.

An FGC conditioning agent injection-control system, where conditioning agent over- or under-injection can be prevented while maximizing a precipitator's performance. The injection rate is typically regulated using feed forward signal proportional to the coal flow, which could be represented by the boiler load augmented by a feedback from the voltage control and electrical conditions in the ESP, sulfur dioxide emissions signaling any changes in the coal quality, opacity monitor data, and other parameters. Both the feed forward and the feedback information and signals from the existing injection skids are analyzed, and the optimal injection rate for the current conditions is determined. With fast, continuous and automatic sampling and analysis, the system responds quickly as each parameter changes, recalculating the optimal injection rate and automatically sends the new injection set-point to the injection skid.

A smoke removal device includes a connecting tube, a burner, and a plurality of heat storage meshes. The connecting tube has an inlet end and an outlet end. The burner is disposed in the connecting tube and has a flame outlet. The heat storage meshes are sequentially disposed between the flame outlet and the outlet end. The heat storage meshes includes a first heat storage mesh and a second heat storage mesh. The first heat storage mesh is located between the second heat storage mesh and the flame outlet. A mesh-number of per unit area of the first heat storage mesh is larger than that of the second heat storage mesh. The first heat storage mesh and the second heat storage mesh could slow down a flow rate of flame to increase temperatures of the heat storage meshes. The smoke is burned off once touching the heat storage meshes.

The present invention relates generally to the field of emission control equipment for boilers, heaters, kilns, or other flue gas-, or combustion gas-, generating devices (e.g., those located at power plants, processing plants, etc.) and, in particular to a new and useful method and apparatus for reducing and/or eliminating various liquid discharges from one or more emission control equipment devices (e.g., one or more wet flue gas desulfurization (WFGD) units). In another embodiment, the method and apparatus of the present invention is designed to reduce and/or eliminate the amount of liquid waste that is discharged from a WFGD unit by subjecting the WFGD liquid waste to one or more drying processes, one or more spray dryer (or spray dry) absorber processes, and/or one or more spray dryer (or spray dry) evaporation processes.