A method and system for cost effectively converting a feedstock using thermal plasma, or other styles of gassifiers, into a feedwater energy transfer system. The feedstock can be any organic material, or fossil fuel. The energy transferred in the feedwater is converted into steam which is then injected into the low turbine of a combined cycle power plant. Heat is extracted from gas product issued by a gassifier and delivered to a power plant via its feedwater system. The gassifier is a plasma gassifier and the gas product is syngas. In a further embodiment, prior to performing the step of extracting heat energy, there is provided the further step of combusting the syngas in an afterburner. An air flow, and/or EGR flow is provided to the afterburner at a rate that is varied in response to an operating characteristic of the afterburner. The air flow to the afterburner is heated.

The current invention disclose a method and apparatus for production of hot water or steam in a firetube boiler, said method comprising the steps of producing a first flue gas using a first stage of a burner in a first pass of a firetube boiler; passing at least a portion of said first flue gas through a second pass of said boiler, wherein said second pass comprises a plurality of firetubes; routing said portion of said first flue gas to a second stage of said burner to reduce NOx emissions from said second stage of said burner; producing a second flue gas from said second stage of said burner in a third pass of said boiler; passing said second flue gas through a fourth pass of said boiler, wherein said fourth pass comprises a plurality of firetubes.

A steam generator for a power plant sub-system, having at least one evaporator tube through which a flow medium can flow, as well as a number of heat exchanger surfaces formed by the surface of the evaporator tube, wherein at least parts of the/each heat exchanger surface are provided with a catalytically active coating for the exothermic decomposition of hydrocarbons. By means of the catalytic coating of the heat exchanger surfaces of the evaporator tubes, an increased heat requirement calculation can be carried out, without also having to accept the formation of unwanted harmful substances inside the steam generator.

A particle separator module and a heat exchange chamber module connectable to a circulating fluidized bed boiler. The particle separator module includes 2N vertically aligned steam tubes, N being an integer greater than one. Each of the vertically aligned steam tubes is attached to a boiler upper portion and extends downwards to a predetermined level. Each of the 2N vertically aligned steam tubes is attached to one of N first beams. Each of the N first beams is suspended to hang in a horizontal position at the predetermined level by two adjacent steam tubes of the 2N vertically aligned steam tubes. N second beams are attached in a horizontal position to the top surface of the heat exchange chamber module, which is arranged to be suspended from the particle separator module by having each of the N second beams suspended by two adjacent beams of the N first beams.

A method for capturing carbon dioxide from a flue gas includes (i) removing moisture from a flue gas to yield a dried flue gas; (ii) compressing the dried flue gas to yield a compressed gas stream; (iii) reducing the temperature of the compressed gas stream to a temperature T.sub.1 using a first heat exchanger; (iv) reducing the temperature of the compressed gas stream to a second temperarature T.sub.2 using a second heat exchanger stream, where T.sub.2<T.sub.1 and at least a portion of the carbon dioxide from the compressed gas stream condenses, thereby yielding a solid or liquid condensed-phase carbon dioxide component and a light-gas component; (v) separating purities the condensed-phase component from the light-gas component to produce a condensed-phase stream and a light-gas stream; and (vi) using at least a portion of the condensed-phase stream and/or the light-gas stream in the second heat exchanger.

A method and system for cost effectively converting a feedstock using thermal plasma, or other styles of gassifiers, into a feedwater energy transfer system. The feedstock can be any organic material, or fossil fuel. The energy transferred in the feedwater is converted into steam which is then injected into the low turbine of a combined cycle power plant. Heat is extracted from gas product issued by a gassifier and delivered to a power plant via its feedwater system. The gassifier is a plasma gassifier and the gas product is syngas. In a further embodiment, prior to performing the step of extracting heat energy, there is is provided the further step of combusting the syngas in an afterburner. An air flow, and/or EGR flow is provided to the afterburner at a rate that is varied in response to an operating characteristic of the afterburner. The air flow to the afterburner is heated.

A fluid recirculation system includes an arrangement of a flow control valve located to receive a flow of fluid from an inlet. The system further comprises an economizer inlet mixing device located to receive the flow of hotter fluid from the arrangement of the flow control valve and from a cooler feedwater stream. An economizer inlet mixing device located upstream of an economizer in a supercritical pressure boiler includes a sparger assembly through which a flow of fluid from the waterwall outlet is received, an inlet through which a flow of fluid from a feed stream is received, and a wave breaker assembly through which an outlet stream from the economizer inlet mixing device is directed.

A method and system for cost effectively converting a feedstock using thermal plasma, or other styles of gassifiers, into to a feedwater energy transfer system. The feedstock can be any organic material, or fossil fuel. The energy transferred in the feedwater is converted into steam which is then injected into the low turbine of a combined cycle power plant. Heat is extracted from gas product issued by a gassifier and delivered to a power plant via its feedwater system. The gassifier is a plasma gassifier and the gas product is syngas. In a further embodiment, prior to performing the step of extracting heat energy, there is provided the further step of combusting the syngas in an afterburner. An air flow, and/or EGR flow is provided to the afterburner at a rate that is varied in response to an operating characteristic of the afterburner. The air flow to the afterburner is heated.

In some aspects, a computer-implemented method of reducing a rate of fouling in a recovery boiler system is provided. A computing device receives boiler operating information for a period of time. The boiler operating information includes boiler operating parameters and a rate of fouling for the period of time. The boiler operating parameters include one or more boiler input parameters. The computing device performs a regression analysis to determine at least one correlation between the boiler operating parameters and the rate of fouling. The computing device causes at least one boiler input parameter to be adjusted based on the at least one correlation to minimize the rate of fouling. In some aspects, a system configured to perform such a method is provided. In some aspects, a computer-readable medium having instructions stored thereon that cause a computing device to perform such a method is provided.