Abstract: A method is provided which refurbishes a Rankine cycle vapor generator initially having a plurality of Rankine heaters for supporting a Rankine cycle subsystem. The method removes at least one of the Rankine heaters, and replaces the at least one removed Rankine heater with a non-Rankine heater for a Kalina cycle subsystem. The vapor generator comprises a first plurality of tubes for receiving a first working fluid, and a second plurality of tubes for receiving a second working fluid. The first plurality of tubes are directed along a first path exposed to heat from a heat source to increase the temperature of the first working fluid within the first plurality of tubes. The second plurality of tubes are directed along a second path exposed to heat from the heat source to increase the temperature of the second working fluid within the second plurality of tubes.

Abstract: A system and method of injecting an ammonia or urea reactant into a flue gas stream in a steam generating power plant that utilizes Selective Catalytic Reduction (SCR) to lower NO.sub.x emissions and more specifically the injection of the reactant in such a manner that a more uniform mixing of the reactant with the flue gas stream is achieved more rapidly thereby increasing the efficiency of the catalytic reduction process and further a method of increasing the amount of reaction that takes place between the reactant/flue gas mixture and the catalytic material.

Abstract: A method of separating unburned Carbon, as particulate matter, from the flyash produced as a result of the combustion process occurring in a pulverized-coal fired steam generating power plant is disclosed. More particularly the invention separates the flyash into a coarse product group and a fine product group by utilizing the differences in specific gravity between the Carbon particles and remaining flyash as well as utilization of the dynamic classification characteristics of a rotary classifier to effect the separation whereby at least one of the two product groups comprises a relatively low weight percentage of unburned Carbon while yet comprising a relatively high percentage of the total mass of product recovered after separation.

Abstract: A fluidized bed combustion system is disclosed and in particular a fluidized bed combustion system particularly well suited for the combustion of oil shale, generating steam thereby. The fluidized bed combustion system includes a furnace volume having a multi-chambered upper segment thereof, a deentrainment zone, a fluidized bed having a plurality of isolatable segments thereof, a fluidized bed ash cooler having a plurality of isolatable segments thereof wherein the fluidized bed ash cooler is in fluid communication with the furnace volume, a fuel supply means in fluid communication with the furnace volume for delivering oil shale thereto for combustion therein, a backpass volume defined by a plurality of backpass wall tubes integral to a thermodynamic steam cycle and in fluid flow relation with the furnace volume and a plurality of circulatory fluid flow paths integral to a thermodynamic steam cycle and operative to conduct the flow of steam or water therethrough.

Abstract: A method for effecting control over a radially stratified flame core burner that is particularly suited for employment in a firing system of a fossil fuel-fired furnace for purposes of reducing the NO.sub.X emissions from the fossil fuel-fired furnace. The subject method for effecting control over a radially stratified flame core burner enables the foregoing to be accomplished while yet at the same time minimizing CO emissions and the opacity of the exhaust from the stack of the fossil fuel-fired furnace without extending the envelope of the flame produced by the radially stratified flame core burner.

Abstract: A method and apparatus for controlling the temperature of a flue gas stream entering a Selective Catalytic Reduction chamber in a steam generating power plant that utilizes Selective Catalytic Reduction (SCR) to lower NO.sub.x emissions is disclosed. The method involves the utilization of superheated steam to control the temperature of the flue gas prior to the flue gas entering the Selective Catalytic Reduction chamber such that there is a reduction in lost energy to the thermodynamic steam cycle caused by spray desuperheating.

Abstract: A separated overfire air injection system particularly suited for use in a fossil fuel-fired steam generating power plant and more specifically to a sixpoint separated overfire air tangential firing system employed in such power plants, particularly those embodying dual-chambered furnaces. A method of operating such a fossil fuel-fired steam generating power plant equipped with the sixpoint separated overfire air injection system of the present invention is also disclosed. The separated overfire injection system in accordance with the present invention includes six SOFA windboxes strategically located about the perimeter of the dual-chambered furnace volume so as to be operative to inject separated overfire air into the furnace volume in such a manner as to engage a fireball symmetrically tangential to a circle.

Abstract: A method of controlling the operation of the bowl mills in a coal-fired steam generating power plant is disclosed; and in particular a method of controlling the operation of such bowl mills such that the furnace of a steam generating power plant can more rapidly respond to abrupt changes in the demands placed upon the output of the furnace due to abrupt changes in the power requirements of an electric power grid.

Abstract: A method for exercising control over the final predefined superheat outlet steam temperature and for exercising control over the final predefined reheat outlet steam temperature from a circulating fluidized bed steam generator having a furnace volume embodying at least superheat surface, a multichambered backpass volume embodying at least superheat surface within one chamber of the multichambered backpass volume and at least reheat surface within another one of the multichambered backpass volume, a first circulatory fluid flow path operative as an evaporative steam loop, and a second circulatory fluid flow path operative as a superheat steam-reheat steam loop and including a saturated steam segment, a superheat steam segment, a reheat steam segment and an economizer segment.

Abstract: A segmented smelt spout comprising an assembly of different casting shapes wherein one shape constitutes the base segment, which is installable in a chemical recovery unit, and the other shapes are a combination of straight and curved cast segments, which can be used in different combinations to obtain varying spout angles and lengths with the latter segments being supported off the base segment and being held together by a tensioning means that maintains contact between the mating surfaces of each segment while permitting each individual segment to expand and contract thermally.

Abstract: A control scheme for large circulating fluidized bed steam generators (CFB) wherein direct control is effected therewith over the temperature of the large circulating fluidized bed steam generators (CFB) and wherein independent control is effected therewith over the final superheat steam temperature of the large circulating fluidized bed steam generators (CFB) as well as over the final reheat steam temperature of the large circulating fluidized bed steam generators (CFB).

Abstract: A system including a resonant cavity for measuring in-situ and in real time the Carbon content of the fly ash produced from the combustion process occurring within a pulverized coal-fired steam generator. The resonant cavity basically includes an intelligence section, a transmitting section, a cavity section and a receiving section. When the system including the resonant cavity is so employed the measurements gained therefrom may be utilized either by an operator or as input to a boiler control system or both in order that corrective action may be implemented when such is required.

Abstract: A control system particularly suited for effecting control over an integrated gasification combined cycle system (IGCC) that includes at least a fuel feed system, a gasifier system, a product gas cleanup system, a booster compressor and a gas turbine. The subject control system includes a bleed air control valve, a booster compressor bypass control valve, a fuel feed control valve and a product gas shutoff valve. The bleed air control valve, which is connected in fluid flow relation between the gas turbine and the booster compressor of the IGCC, is operable for effecting control over the amount of air that is bled in the IGCC. The booster compressor bypass control valve, which is connected in fluid flow relation between the upstream side and the downstream side of the IGCC, is operable for effecting the bypass of air around the booster compressor of the IGCC.

Abstract: A method for enhancing the minimization of NO.sub.x control in a circulating fluid bed steam generator into which there is injected fuel, fluidizing air, a lower level of combustion air and an upper level of combustion air. The fuel is injected at a first location, the fluidizing air is injected at a second location, the lower level of combustion air is injected at a third location and the upper level of combustion air is injected at a fourth location. In order to enhance the minimization of NO.sub.x control within a circulating fluid bed steam generator the lower level combustion air as well as the upper level combustion air are each biased in the horizontal plane as well as the vertical plane so as to thereby control the lower level combustion air flow and the upper level combustion air flow such that local stoichiometries within the circulating fluid bed steam generator are maintained within a range of 70% stoichiometry to 90% stoichiometry.

Abstract: A control system for a fuel-fired furnace and more specifically the control of the stoichiometric ratio of the combustion process occurring within the furnace of a steam generating power plant. The control system, when so employed, is capable of regulating the distribution of air flow to the combustion process such that the formation of oxides of nitrogen are maintained at acceptable levels. The control system includes in general a stoichiometric subsystem that determines the mass flow rate of air required to maintain the stoichiometric ratio within the combustion process; an override protection subsystem which ensures control precedence of the windbox-to-furnace pressure differential over the stoichiometry subsystem; and an overfire air subsystem that acts to apportion air flow amongst the various levels of overfire air within the boiler.

Abstract: A high performance, multi-stage, pressurized, airblown, entrained flow coal gasifier system and a method of operating such a gasifier system for generating therewithin fuel gas from coal. The subject gasifier system includes an outer, pressure containing vessel surrounding an inner, water-cooled vessel wherein the gasification reaction, through which the fuel gas is generated from coal, takes place. The inner, water-cooled vessel embodies a first stage within which the high temperatures required for the gasification reactions to take place as well as for slagging are generated from the combustion of char, a second stage within which the char is gasified to generate the subject fuel gas, and a third stage within which coal is devolatilized to produce the char for the first stage and the second stage and with a concomitant quenching being effected of the fuel gas as the latter flows through the third stage of the inner water-cooled vessel.

Abstract: A high performance, multi-stage, pressurized, airblown, entrained flow coal gasifier system and a method of operating such a gasifier system for generating therewithin fuel gas from coal. The subject gasifier system includes an outer, pressure containing vessel surrounding an inner, water-cooled vessel wherein the gasification reaction, through which the fuel gas is generated from coal, takes place. The inner, water-cooled vessel embodies a first stage within which the high temperatures required for the gasification reactions to take place as well as for slagging are generated from the combustion of char, a second stage within which the char is gasified to generate the subject fuel gas, and a third stage within which coal is devolatilized to produce the char for the first stage and the second stage and with a concomitant quenching being effected of the fuel gas as the latter flows through the third stage of the inner water-cooled vessel.

Abstract: A black liquor gasification system intended for use as a replacement for a Tomlinson cycle, Chemical Recovery Unit, and which operates at a temperature below the ash melting temperature thereby removing the potential for smelt-water reactions and explosions. The subject black liquor gasification system is based on the use of a circulating fluidized bed operating at atmospheric pressure that produces dry, recoverable salts as well as low calorific gases to be used within the paper-making process.

Abstract: A slag tap system for a pressurized gasifier system that includes a reaction vessel and a pressure vessel in surrounding relation to the reaction vessel.