A water feeding system provided with: a first feed water line through which first feed water flows; a second feed water line through which second feed water having a lower pressure than the first feed water flows; a first heater that heats the first feed water; a first feed water introducing line that guides first heated feed water, which is the first feed water that has been heated by the first heater, to the second feed water line; a medium heat exchanger that causes the first heated feed water to exchange heat with a medium, thereby cooling the first heated feed water and heating the medium; and a cooling water injecting line that injects cooling water having a lower temperature than the first heated feed water into the first feed water introducing line, at a position located further to the second feed water line side than the medium heat exchanger.

A water feeding system provided with: a first feed water line through which first feed water flows; a second feed water line through which second feed water having a lower pressure than the first feed water flows; a first heater that heats the first feed water; a first feed water introducing line that guides first heated feed water, which is the first feed water that has been heated by the first heater, to the second feed water line; a medium heat exchanger that causes the first heated feed water to exchange heat with a medium, thereby cooling the first heated feed water and heating the medium; and a cooling water injecting line that injects cooling water having a lower temperature than the first heated feed water into the first feed water introducing line, at a position located further to the second feed water line side than the medium heat exchanger.

The method in a recovery boiler comprises estimating the first melting temperature T.sub.0 of the fly ash depositing on heat transfer surfaces, the estimating being based on potassium (K) content of the fly ash; measuring or estimating the temperature T.sub.ss of superheated steam; evaluating a temperature difference T.sub.D1 between the first melting temperature T.sub.0 and the temperature T.sub.ss of the superheated steam, the temperature difference T.sub.D1 providing an estimate of the risk of corrosion; and selecting a control action for influencing the temperature difference T.sub.D1. Alternatively or additionally, the method comprises estimating the sticky temperature T.sub.STK of the fly ash depositing on heat transfer surfaces, the estimating being based on potassium (K) and chlorine (Cl) contents of the fly ash; measuring or estimating the temperature T.sub.FG of the flue gases; evaluating a temperature difference T.sub.D2 between the sticky temperature T.sub.STK and the temperature T.sub.FG of the flue gases; the temperature difference T.sub.D2 providing an estimate of the risk of plugging; and selecting a control action for influencing the temperature difference T.sub.D2.

The method in a recovery boiler comprises estimating the first melting temperature T.sub.0 of the fly ash depositing on heat transfer surfaces, the estimating being based on potassium (K) content of the fly ash; measuring or estimating the temperature T.sub.ss of superheated steam; evaluating a temperature difference T.sub.D1 between the first melting temperature T.sub.0 and the temperature T.sub.ss of the superheated steam, the temperature difference T.sub.D1 providing an estimate of the risk of corrosion; and selecting a control action for influencing the temperature difference T.sub.D1. Alternatively or additionally, the method comprises estimating the sticky temperature T.sub.STK of the fly ash depositing on heat transfer surfaces, the estimating being based on potassium (K) and chlorine (Cl) contents of the fly ash; measuring or estimating the temperature T.sub.FG of the flue gases; evaluating a temperature difference T.sub.D2 between the sticky temperature T.sub.STK and the temperature T.sub.FG of the flue gases; the temperature difference T.sub.D2 providing an estimate of the risk of plugging; and selecting a control action for influencing the temperature difference T.sub.D2.

A thermal power generation system includes: a boiler; at least one steam turbine; a generator; a condenser; at least one low-pressure feed water; a high-pressure feed water pump; at least one high-pressure feed water heater capable of heating water pumped by the high-pressure feed water pump by utilizing extracted steam; a catalyst device including at least one kind of catalyst capable of promoting reduction reaction of nitrogen oxide and oxidation reaction of metallic mercury, the nitrogen oxide and the metallic mercury both being contained in the exhaust gas; at least one mercuric oxide removing device capable of removing mercuric oxide produced by the oxidation reaction of the metallic mercury from the exhaust gas; and an exhaust gas temperature adjustment device capable of adjusting a temperature of the exhaust gas at the catalyst device, by adjusting heating of the water by the at least one high-pressure feed water heater.

A thermal power generation system includes: a boiler; at least one steam turbine; a generator; a condenser; at least one low-pressure feed water; a high-pressure feed water pump; at least one high-pressure feed water heater capable of heating water pumped by the high-pressure feed water pump by utilizing extracted steam; a catalyst device including at least one kind of catalyst capable of promoting reduction reaction of nitrogen oxide and oxidation reaction of metallic mercury, the nitrogen oxide and the metallic mercury both being contained in the exhaust gas; at least one mercuric oxide removing device capable of removing mercuric oxide produced by the oxidation reaction of the metallic mercury from the exhaust gas; and an exhaust gas temperature adjustment device capable of adjusting a temperature of the exhaust gas at the catalyst device, by adjusting heating of the water by the at least one high-pressure feed water heater.

An exhaust gas latent-heat recovery device includes: a heat transfer tube disposed inside a duct through which exhaust gas flows, the heat transfer tube having a water supply inlet into which water to be heated for recovering latent heat of the exhaust gas is supplied and a water supply outlet through which the water to be heated is discharged; and a water supply control part configured to control supply of the water to be heated to the water supply inlet. The water supply control part is configured to control supply of the water to be heated from the water supply inlet so that an outlet temperature being a temperature of the water to be heated at the water supply outlet is at a set temperature.

An exhaust gas latent-heat recovery device includes: a heat transfer tube disposed inside a duct through which exhaust gas flows, the heat transfer tube having a water supply inlet into which water to be heated for recovering latent heat of the exhaust gas is supplied and a water supply outlet through which the water to be heated is discharged; and a water supply control part configured to control supply of the water to be heated to the water supply inlet. The water supply control part is configured to control supply of the water to be heated from the water supply inlet so that an outlet temperature being a temperature of the water to be heated at the water supply outlet is at a set temperature.

A feed-water discharge side of a condenser is connected to a feed-water entry side of an flue gas cooler through a bypass line provided with a steam production preventive pump and with an inlet cutoff valve. A feed-water discharge side of the flue gas cooler is connected to the feed-water entry side of the condenser through a steam production preventive water circulation line provided with an outlet cutoff valve. When a boiler feed-water pump is stopped in boiler fuel cutoff, the inlet and outlet cutoff valves are opened and the steam production preventive pump is activated to cause water to flow through the bypass line into the flue gas cooler, is returned through the steam production preventive water circulation line to the condenser and is circulated.

A feed-water discharge side of a condenser is connected to a feed-water entry side of an flue gas cooler through a bypass line provided with a steam production preventive pump and with an inlet cutoff valve. A feed-water discharge side of the flue gas cooler is connected to the feed-water entry side of the condenser through a steam production preventive water circulation line provided with an outlet cutoff valve. When a boiler feed-water pump is stopped in boiler fuel cutoff, the inlet and outlet cutoff valves are opened and the steam production preventive pump is activated to cause water to flow through the bypass line into the flue gas cooler, is returned through the steam production preventive water circulation line to the condenser and is circulated.