Abstract: A control module is able to be installed with electrical devices, such as, for example electrical loads (e.g., lighting loads) and/or load regulation devices. The control module may determine whether an LED driver for an LED light source is responsive to one or more of a plurality of control techniques. The control module may be able to automatically determine an appropriate control technique to use to control the connected LED driver and/or LED light source. The control module may sequentially attempt to control the LED driver and/or LED light source using each of the plurality of control techniques and determine if the LED driver and/or LED light source is responsive to the present control technique. The plurality of control techniques may include one or more analog control techniques and one or more digital control techniques.

Abstract: Supercritical fluid systems and aircraft power systems are described. The systems include a compressor, a turbine operably coupled to the compressor, a generator operably coupled to the turbine and configured to generate power, a primary working fluid flow path having a primary working fluid configured to pass through the compressor, a separator, the turbine, and back to the compressor, and a secondary working fluid flow path passing through the generator, the compressor, the separator, and back to the generator. The primary working fluid is supercritical carbon dioxide (sCO2) and the secondary working fluid is a fluid having at least one of a density less than the primary working fluid and a molecular size smaller than the primary working fluid.

Abstract: A method of reducing the emission of nitrogen oxides (NOx) during system startup of a power generating system may include igniting a combustion turbine thereby generating exhaust, supplying the exhaust to a catalyst bed comprising a selective catalytic reduction (SCR) catalyst, injecting an initial pulse of ammonia into the exhaust during a storage period such that the NOx reacts with the ammonia and is stored in the catalyst bed as ammonium nitrate (AN) during the storage period; and injecting a scheduled amount of ammonia into the exhaust during a transition period such that the stored AN is decomposed as temperatures increase and NOx is converted via standard and fast SCR reactions during the transition period.

Abstract: Provided is a new binary power generation system that, in the binary power generation system using exhaust gas as a heating source, maximizes the power generation amount while considering the sulfuric acid dew point temperature of the exhaust gas. In this binary power generation system, corrosion due to sulfuric acid is prevented. Provided is a binary power generation system including a binary power generation apparatus that generates power by vaporizing a power generation medium using heat of exhaust gas output from a drive apparatus, wherein the binary power generation apparatus includes a control section that controls a mass flow rate of the power generation medium based on at least a sulfur concentration of the exhaust gas.

Abstract: A remodeling method of a combined cycle plant including gas turbines; heat recovery steam generators provided corresponding to number of the gas turbines and configured to recover heat of flue gas discharged from the gas turbines and produce steam by the recovered heat; ducts configured to guide the flue gas from the gas turbines toward the respective heat recovery steam generators; and a steam turbine configured to be rotationally driven by the steam produced by the heat recovery steam generators. The remodeling method of a combined cycle plant includes: removing gas turbines and ducts; installing, in place of the two gas turbines, a new gas turbine that is higher in efficiency and smaller in number than the two gas turbines; and installing, in place of the ducts, a distribution duct configured to distribute and guide flue gas from the new gas turbine to two heat recovery steam generators.

Abstract: Solar/Rankine steam cycle hybrid concentrating solar power (CSP) systems and methods for designing or retrofitting existent natural circulation boilers using saturated or superheated steam produced by direct steam generation (DSG) or Heat Transfer Fluid (HTF) steam generators and CSP solar field technology systems are described. Additionally, methods and processes of retrofitting the existent Heat Recovery Steam Generators (HRSG) or biomass, gas, oil or coal fired boilers to operate integrated to a molten salt/water-steam heat exchangers are disclosed. The hybrid CSP systems are highly efficient due to the increase of steam generated by the solar section comprising either the DSG receiver or the molten salt-water-steam sequential heat exchangers, pre-heaters, boiler/saturated steam generators, super-heaters and re-heaters.

Abstract: Cogeneration system (200, 300) comprising: a boiler (201, 301) able to heat water for domestic use; a combustor (201a, 301a) placed into the boiler; a compressor (204, 304); a heat exchanger (202, 302) for the exchange of thermal energy between the combustion fumes generated in the combustor (201a, 301a) and a fluid coming from the compressor (204, 304); a gas turbine (203, 303); a current generator (205, 305) and a current converter (206, 306) able to produce electrical energy; a main fumes/water exchanger (207, 307) able to recover thermal energy. The cogeneration system (200, 300) comprises also a by-pass valve (210, 310) configured to adjust the flow of fluid entering the gas turbine (203, 303).

Abstract: A regenerative compressed air energy storage system and a using method thereof. The system comprises a compressor unit, a high-temperature heat exchanger, a medium-temperature heat exchanger, an air storage chamber, a regulating valve, a medium-temperature regenerator, a high-temperature regenerator and an expander unit which are connected in sequence. The low-temperature side of the high-temperature heat exchanger, a high-temperature heat reservoir, a first valve, the high-temperature side of the high-temperature regenerator, a high-temperature cold reservoir and a second valve are connected in sequence. The low-temperature side of the medium-temperature heat exchanger, a medium-temperature heat reservoir, a third valve, the high-temperature side of the medium-temperature regenerator, a medium-temperature cold reservoir and a fourth valve are connected in sequence.

Abstract: A gas turbine combined cycle plant includes a fuel gas heater configured to heat fuel gas to be supplied to a combustor of a gas turbine using heated water heated by an exhaust heat recovery boiler; a return valve disposed on a heated water returning line to return heated water passing through the heater to the boiler; a dump valve disposed on a condensate line bifurcated from the heated water returning line between the return valve and the heater to return the heated water to a condenser; and a control unit configured to control operation of the return and dump valves. When load of the turbine falls below a lower limit, the control unit closes the return valve and keeps the opening degree of the dump valve at a specified degree to reduce a flow rate of the heated water flowing in the heater for a predetermined time.

Abstract: An apparatus for rapidly evaporating liquid includes an exhaust flow channel having opposing openings including an upstream opening and a downstream opening. The channel defines an exhaust path proceeding from the upstream opening through the exhaust flow channel and through the downstream opening. Within the exhaust flow channel, a conduit path includes repeated passes transverse to the exhaust path. Attached to the exhaust flow channel proximate the downstream opening, a spray fixture is coupled to an exit port of the conduit. The spray fixture includes a divider to divide fluid from the exit port into multiple streams and an aimer to direct the multiple streams into the exhaust path.

Abstract: A control system is provided for a modulated heating system including a plurality of modulating water heaters, which may be modulating boilers. A deadband control scheme provides for reduced cycling of the modulating heater when total system heat demand falls between the maximum output of one heater and the sum of the maximum output of that one point and the minimum firing point of the next subsequent heater. Condensation of flue gas products is prevented by monitoring flue exhaust temperature for each heater and controlling the modulation of each heater to maintain a minimum heater output sufficiently high to prevent condensation of flue gas products from that heater. Rapid reaction to changes in system heat demand is provided by sensing changes in flow rate in a primary loop of the system and anticipating resulting changes in temperature thus allowing for change in heater output prior to the time the change in flow rate has fully impacted system temperature.

Abstract: Inlet air heating systems for combined cycle power plants and combined cycle power plants including inlet air heating systems are disclosed. The inlet air heating systems may include a plurality of heating coil assemblies partially positioned within an inlet housing of a gas turbine system, and a vent valve in fluid communication with each of the heating coils. The inlet air heating system may also include a supply line in fluid communication with the heating coils to provide water to the heating coils, and a hot water line in fluid communication with the supply line and a component positioned downstream of a condenser of the combined cycle power plant. The hot water line may provide hot water from the combined cycle power plant to the supply line. Additionally, the inlet air heating system may include a drain line in fluid communication with the heating coils and the condenser.

Abstract: A power plant comprises a boiler, a turbine, a condenser, a feed water heater, a deaerator, a deaerator water level control valve, an extraction system which introduces the steam extracted from the turbine into the feed water heater, an extraction valve, an auxiliary steam introduction system which introduces auxiliary steam into the feed water heater, an auxiliary steam control valve and a control device. When a rapid load increase request is made, the control device controls, to orient the extraction valve in a closing direction, to maintain an opening of the deaerator water level control valve, and to orient the auxiliary steam control valve in an opening direction.

Abstract: In one embodiment, a plant control apparatus controls a power plant, which includes a gas turbine, a generator driven by the gas turbine, an exhaust heat recovering boiler to generate first steam using heat of exhaust gas from the gas turbine, a steam turbine driven by the first steam, and a clutch to connect a first shaft connected to the gas turbine and generator with a second shaft connected to the steam turbine. The apparatus includes a starting module to start the gas turbine and generator while holding the steam turbine in a stop state, when the clutch is in a released state. The apparatus further includes a warming module to warm the steam turbine by supplying second steam from equipment different from the boiler to the steam turbine in parallel with the starting of the gas turbine and generator, when the clutch is in a released state.

Abstract: A gas turbine combined cycle (GTCC) power generation plant (100) equipped with a control unit which performs a load reduction following operation with respect to a fuel adjustment valve (Vd), a main steam valve (V1), and a bypass valve (V4), wherein, when a load reduction request for reducing a GTCC load target value has been input in a closed bypass operation, the degree of opening of the fuel adjustment valve (Vd) is reduced in accordance with the target value while the main steam valve (V1) is in an open state, and the bypass valve (V4) is placed in an open state, after which the bypass valve (V4) is placed in the closed state when the GTCC load reaches the target value.

Abstract: A steam turbine is for a combined cycle plant. The combined cycle plant includes a gas turbine; a boiler a heat source of which is a flue gas discharged from the gas turbine; a high-pressure steam turbine that includes a rotor extending along an axial center of rotation of the rotor, a steam passage provided along the extending direction of the rotor between the rotor and a casing for the rotor, and a high-pressure steam supply portion provided to communicate, from outside the casing through the casing, with the steam passage and configured to be supplied with superheated steam, the high-pressure steam turbine being driven by high-pressure steam generated by the boiler; and a low-pressure steam turbine configured to be driven by low-pressure steam generated by the boiler and by the steam that has flowed through the high-pressure steam turbine.

Abstract: A compressed air energy storage generator includes a motor, a compressor, a pressure accumulator, an expander, a generator, an electric-motor inverter, a generator inverter, a feed command receiver, a discharge command receiver, and a controller. The controller includes a feed determination unit, a discharge determination unit, and an input and output adjustment unit, the feed determination unit being configured to determine whether a feed command value is smaller than minimum charge power, the discharge determination unit being configured to determine whether a discharge command value is smaller than minimum discharge power, the input and output adjustment unit being configured to control, when the feed determination unit determines that the feed command value is smaller than the minimum charge power or when the discharge determination unit determines that the discharge command value is smaller than the minimum discharge power, the inverters to simultaneously drive the motor and the generator.

Abstract: The present invention relates to a gas-steam combined cycle centralized heat supply device and a heat supply method. The gas-steam combined cycle centralized heat supply device comprises a gas-steam combined cycle system connected with a thermal station through a heating network return water heating system; the gas-steam combined cycle system comprises a gas turbine connected with a direct contact type flue gas condensation heat exchanger and a steam turbine via a waste heat boiler; the thermal station comprises a hot water type absorption heat pump and a water-water heat exchanger; the heating network return water heating system comprises a steam type absorption heat pump for recovering flue gas waste heat and a steam-water heat exchanger. The present invention can be widely applied to the industry of power plant waste heat recovery.

Abstract: A combined cycle power plant comprises a combustion turbine generator, another heat source in addition to the combustion turbine generator, a steam power system, and an energy storage system. Heat from the heat source, from the energy storage system, or from the heat source and the energy storage system is used to generate steam in the steam power system. Heat from the combustion turbine generator exhaust gas may be used primarily for single phase heating of water or steam in the steam power system. Alternatively, heat from the combustion turbine generator exhaust gas may be used in parallel with the energy storage system and/or the other heat source to generate steam, and additionally to super heat steam. Both the combustion turbine generator and the steam power system may generate electricity.

Abstract: In one embodiment, a plant control apparatus controls a power plant that includes a combustor to burn fuel with oxygen introduced from an inlet guide vane to generate gas, a gas turbine driven by the gas from the combustor, a heat recovery steam generator to generate steam using heat of an exhaust gas from the gas turbine, and a steam turbine driven by the steam from the heat recovery steam generator. The apparatus controls an angle of the inlet guide vane before a start of the steam turbine to a first angle, controls the angle of the inlet guide vane after the start of the steam turbine to a second angle larger than the first angle, and reduce the angle of the inlet guide vane from the second angle to the first angle or more during the predetermined period.

Abstract: A combined cycle power plant feedwater system includes: a feed pump which supplies feedwater to a heat recovery steam generator; a first pipe which extracts part of the feedwater from a flow path in mid-course of pressurization of the feed pump; a first boiler supplied with the feedwater led into the first pipe and subjected to first water treatment; a second pipe where the feedwater discharged from a feed pump outlet flows; a second boiler supplied with the feedwater led into the second pipe and subjected to second water treatment more downstream than the flow path in mid-course of the pressurization; and a water-treating substance supply device which supplies a water-treating substance for the second water treatment to the feedwater flow path in the feed pump, at a position more downstream than a connection position of the first pipe and more upstream than a connection position of the second pipe.

Abstract: A power generating system includes a condensing steam turbine fed with steam from a boiler, wherein the air supply for the boiler combustion process is preheated by means of a heat pump system comprising at least one heat pump with at least one compressor, before entry to the boiler. A method for generating power using the power generating system is also described. A method and apparatus for extracting heat from the gases of a combustion process are also described.

Abstract: A method for operating a combined cycle power plant, wherein the combined cycle power plant has a gas turbine and a steam turbine and also a shutting-down device, and wherein, for shutting down the gas turbine and the steam turbine, the gas turbine and the steam turbine are operated within a time window that extends from the beginning of the shutting-down procedure at a first time to the falling of the steam temperature to a lower limit value at a second time by the shutting device in such a way that the gas turbine and the steam turbine are relieved substantially at the same time and the block power falls to zero, thermal energy that is stored in the combined cycle power plant preventing immediate falling of a steam temperature to operation below a minimum power output of the gas turbine within the time window.

Abstract: Embodiments of the present disclosure include a system, method, and apparatus comprising a direct steam generator configured to generate saturated steam or superheated steam and combustion exhaust constituents. A CONVAPORATOR™ Unit (CU) can be fluidly coupled to the direct steam generator. The CU can be configured to route the saturated steam or superheated steam and combustion exhaust constituents through a condenser portion of the CU via a condenser side steam conduit and can be configured to condense the super-heated steam or saturated steam to form a condensate. A separation tank and water return system can be fluidly coupled to a condenser side condensate conduit of the condenser portion of the CU. The separation tank and water return system can be configured to separate the combustion exhaust constituents from the condensate. An evaporator portion of the CU can be fluidly coupled with the separation tank and water return system via an evaporator side condensate conduit.

Abstract: An active clearance control assembly for a gas turbine engine includes a firewall, a fluid intake and an active clearance control manifold. A conduit is configured to direct a fluid from the fluid intake on a first axial side of the firewall through the firewall to at least one active clearance control manifold on a second axial side of the firewall. A valve is located on the first axial side of the firewall and is configured to regulate the flow of the fluid through the conduit.

Abstract: A pulsed pressure, heat recovery system includes a pressure vessel for holding a vaporisable first fluid. The vessel contains a heat exchanger, and provides communication to the heat exchanger for flow of a heated second fluid. The heat exchanger enables heat transfer from the second fluid to vaporise the first fluid. The system also includes a flow loop for the first fluid extending from an outlet of the vessel to an inlet to the vessel, having in series: a first non-return valve, a turbine and a second non-return valve. The first non-return valve allows the vaporised first fluid to flow from the vessel to the turbine when the pressure of the vaporised first fluid in the vessel exceeds a predetermined limit. The turbine extracts energy from expansion of the vaporised first fluid. The second non-return valve prevents flow reversal around flow loop between the turbine and the inlet.

Abstract: A method for operating a gas and steam turbine installation, wherein the heat contained in the expanded flue gas of the gas turbine is used to generate steam for the steam turbine. If a critical operating state arises, the temperature of the expanded flue gas is reduced by introducing water into the expanded flue gas in the flue gas duct between the gas turbine and the waste-heat steam generator connected downstream with regard to flow, wherein the amount of water to be introduced is determined in dependence on the flue gas temperature. The flue gas temperature is measured before water is introduced into the flue gas, an average combustion temperature of the combustion chamber of the gas turbine is determined from the flue gas temperature, and the amount of water to be introduced is set on the basis of the combustion temperature.

Abstract: A system includes an HRSG that includes a plurality of heat exchanger sections fluidly coupled to each other. The plurality of heat exchanger sections comprises at least one economizer, at least one evaporator, at least one reheater, and at least one superheater. In addition, the HRSG includes an additional heat exchanger section coupled to two different heat exchanger sections of the plurality of heat exchanger sections. Further, the HRSG includes a controller programmed to selectively fluidly couple the additional heat exchanger section to one of the two different heat exchanger sections to alter a heat duty for the selected heat exchanger section fluidly coupled to the additional heat exchanger.

Abstract: Provided is a flow path forming plate having a gas path surface that comes in contact with combustion gas, end surfaces formed at peripheral edges of the gas path surface, a first side passage, and a plurality of end surface blow-out passages. The first side passage extends in a direction along a first end surface that is one of the end surfaces, and cooling air flows through the first side passage. A plurality of passage forming surfaces forming the first side passage includes a first forming surface that faces an opposite-flow-path side and extends gradually farther away from the gas path surface while extending toward the first end surface. The end surface blow-out passages open in the first forming surface of the first side passage and in the first end surface.

Abstract: The invention relates a combined cycle power plant with a gas turbine, a shaft connecting a compressor to a turbine, and a first generator, a heat recovery steam generator fluidly connected to the exhaust of the gas turbine.

Abstract: There is provided a supercritical carbon dioxide (CO2) power generation system including a first compression part and a second compression part to independently compress the working fluid; a first regeneration part to heat the working fluid compressed by the first compression part; a second regeneration part to heat the working fluid heated by the first regeneration part and the working fluid compressed by the second compression part; a main heat exchange part to transfer heat generated from a heat source to the working fluid; an expansion part to generate power by expanding the working fluid; a power transmission part to transmit the power; and a power generation part to generate electric power using the power.

Abstract: Systems and methods provide a flow distribution device that includes a duct for a heat recovery steam generators having a duct an expansion portion extending from an inlet portion. The expansion portion has a larger cross-sectional area than the inlet portion. The flow distribution device includes a guide vane having a curved surface. The guide vane is positioned in the duct to extend from at least a part of the inlet portion into the expansion portion.

Abstract: The invention relates to a steam turbine having a plurality of stages comprising a plurality of points of admission connected to a plurality of admission lines, a feed line connected to the plurality of admission lines and at least one extraction line, extending from an intermediate stage of the steam turbine, for extracting steam from the steam turbine. The at least one capacity line fluidly connects an admission lines and at least one extraction line so as to bypass the steam turbine, and is further configured to increase a swallowing capacity of the steam turbine as measured from the feed line upstream of the capacity line compared to the plurality of points of admission.

Abstract: The present disclosure relates to systems and methods that provide power generation using predominantly CO2 as a working fluid. In particular, the present disclosure provides for particular configurations for startup of a power generation system whereby the combustor may be ignited before the turbine is functioning at a sufficiently high speed to drive the compressor on a common shaft to conditions whereby a recycle CO2 stream may be provided to the combustor at a sufficient flow volume and flow pressure. In some embodiments, a bypass line may be utilized to provide additional oxidant in place of the recycle CO2 stream.

Abstract: A method of operating a combined heat and power plant (10) (CHP plant) includes generating hot flue gas in a hot flue gas generator (12) and cooling the hot flue gas in a sequence of cooling steps to recover heat and to generate steam in a heat recovery steam generator (16) (HRSG). The HRSG (16) includes an HP steam evaporator (26) downstream of the hot flue gas generator (12) in which HP steam is generated and in which the hot flue gas is cooled, at least one HP steam superheater (20, 22) between the hot flue gas generator (12) and the HP steam evaporator (26) in which at least HP steam from the HP steam evaporator is superheated and in which the hot flue gas is cooled, and an MP steam superheater (24) upstream of the HP steam evaporator (26) in which MP steam is superheated by the hot flue gas and in which hot flue gas is cooled.

Abstract: A gas turbine engine including a compressor section, a turbine section, and a combustion section positioned between the compressor section and the turbine section is provided. The gas turbine engine also includes a cooling system having a tank and one or more fluid lines in fluid communication with the tank. The one or more fluid lines are configured to carry a flow of consumable cooling liquid provide such consumable cooling liquid to one or more components of the compressor section, the turbine section, and/or the combustion section not directly exposed to a core air flowpath defined through the gas turbine engine.

Abstract: A thermal power plant, in particular to a steam-electric power plant or a combined cycle power plant (CCPP), and a method for operating a thermal power plant is adapted to accelerate, or to technically and/or economically optimize the start-up of the thermal power plant, in particular to accelerate/optimize a cold-start phase of the thermal power station. The thermal power plant has an auxiliary energy store integrated into the power plant. The store, during the start-up of the thermal power plant, delivers energy for heating/pre-heating components and/or media of the thermal power plant, or supplies an electrical power distribution network.

Abstract: A method for operating a power plant may include, during shutdown of a turbine, controlling a damper to move from a first position directing turbine exhaust to enter a heat recovery system to a second position to allow the turbine exhaust to enter a bypass stack and block the turbine exhaust to the heat recovery system. While the position of the damper is maintained in the second position, fired shutdown of the turbine may be performed. In response to instructions to start the turbine, air flow in an exhaust duct for a predetermined period of time is generated, and after generating the air flow for the predetermined period of time, the turbine may be started without performing a purge sequence for the heat recovery system. After starting the turbine, the damper may be controlled between the second position and the first position.

Abstract: A waste heat recovery device includes: a low-boiling-point medium Rankine cycle in which a low-boiling-point medium circulates while the low-boiling-point medium is repeatedly condensed and evaporated; a heated water line that guides liquid water, which is heated here, to the low-boiling-point medium Rankine cycle from a waste heat recovery boiler; and a water recovery line that returns the water, which has passed through the low-boiling-point medium Rankine cycle, to the waste heat recovery boiler. The low-boiling-point medium Rankine cycle includes a heater that heats the low-boiling-point medium by exchanging heat between the low-boiling-point medium, which is a liquid, and liquid water, which has passed through the heated water line.

Abstract: A system includes a system includes an exhaust section which receives an exhaust flow of a gas turbine, where the exhaust section includes a catalyst assembly. The system includes an exhaust duct coupled to the diffuser section upstream of the catalyst assembly, where the exhaust duct extracts a return portion of the exhaust flow. The system includes a filter house coupled to the exhaust duct, where the filter house is receives a combined flow of an ambient air flow and the return portion. The system includes a return conduit coupled to the filter house and the exhaust section, where the return conduit is coupled to the exhaust section upstream of the exhaust duct. The return conduit directs the combined flow to the exhaust section, and the catalyst assembly receives a mixed flow including the exhaust flow and the combined flow.

Abstract: A combined cycle dual closed loop electric generating system, having a gas turbine assembly (having a combustion chamber, a compressor, a first pump, a first driveshaft, a gas turbine and a first generator) and a steam turbine assembly (having a second pump, a second driveshaft, a steam turbine and a second generator). The first portion of the working fluid circulates through the gas turbine assembly and a first heat exchanger. The second portion of the working fluid circulates through the steam turbine assembly and the first heat exchanger. The first heat exchanger transfers a first heat energy from the gas turbine loop to the steam turbine loop. The gas turbine assembly generates a first portion of an electric output. The steam turbine assembly generates a second portion of the electric output.

Abstract: A low-cost hybrid energy storage system receives energy from one or more external sources, and has an air compressor, low-pressure compressed air energy storage (CAES) system that receives compressed air from the compressor, and a low-temperature thermal energy storage (LTES) system that extracts heat generated by the compression of the air. The LTES system heats an expansion air stream released from the CAES system. The expansion air stream is augmented by air from a turbocharger, and further heated by the exhaust stream of a power turbine. At least a portion of the augmented air stream is further heated in a high-temperature thermal energy storage system that receives energy from the one or more external source. The augmented stream is directed to the turbocharger, and then through the power turbine to generate output energy.

Abstract: The present invention relates to an apparatus for managing voltage stability of an electrical power grid and a method therefor.

Abstract: Disclosed is a gas turbine and pressurized water reactor steam turbine combined circulation system, using a heavy duty gas turbine and a pressurized water reactor steam turbine to form a combined circulation system. Heat of the tail gas of the gas turbine is utilized to raise the temperature of a secondary circuit main steam from 272.8° C., and the temperature of the secondary circuit main steam slides between 272.8° C. and 630° C. according to different pressurized water reactor steam yields and different input numbers and loads of the heavy duty gas turbine. The system has a higher heat efficiency than that of the pressurized water reactor steam turbines in the prior art; and as for the electric quantity additionally generated by gas, the heat efficiency of the system is also significantly higher than that of gas-steam combined circulation in the prior art.

Abstract: A method includes determining a commanded load rate of change of an industrial system, wherein the commanded load rate of change comprises a rate of load placed on an industrial machine of the industrial system. The method also includes determining a measured load rate of change of the industrial system based at least in part on an output power of the industrial system. The method further includes determining a variable multiplier based at least in part on the commanded load rate of change and the measured load rate of change. The method also includes applying the variable multiplier to a load rate command to the industrial system to generate a multiplied load rate command. The method further includes sending a signal to the industrial system to control the rate of the load placed on the industrial machine based at least in part on the multiplied load rate command.

Abstract: A method of operating a combined heat and power plant includes, when there is insufficient heat removal from a hot flue gas downstream from a hot flue gas generator but upstream of a steam evaporator, as a result of insufficient mass flow of imported steam to a steam superheater, to prevent the hot flue gas temperature downstream of the steam superheater from rising to or above a predetermined limit, quenching steam inside the steam superheater or quenching steam being fed to the steam superheater by injecting boiler feed water or condensate into the steam to produce steam in the steam superheater. The quenching increases the removal of heat from the hot flue gas and reduces the hot flue gas temperature downstream of the steam superheater to ensure that the hot flue gas temperature downstream of the steam superheater does not rise to or above the predetermined limit.

Abstract: A control for a multi-shaft turbine engine system using electrical machines seeks optimal system performance while accommodating hard and soft component limits. To accommodate the component limits, the control may generate a number of possible operating point options reflecting potential trade-offs in performance, lifting, efficiency, or other objectives.

Abstract: A system may include an exhaust conduit configured to route an exhaust gas from an engine to a heat recovery steam generator (HRSG). The system may also include a coolant supply coupled to the exhaust conduit. The coolant supply is configured to supply a coolant to the exhaust conduit. Additionally, the system may include a controller configured to control the coolant supply to control an exhaust temperature of the exhaust gas flowing through the exhaust conduit from the engine to the HRSG, or a steam temperature of steam generated by the HRSG, or a combination thereof. The controller may be configured to control the coolant supply differently in a full load condition relative to a part load condition of the system.

Abstract: A control system is provided for a modulated heating system including a plurality of modulating water heaters, which may be modulating boilers. A deadband control scheme provides for reduced cycling of the modulating heater when total system heat demand falls between the maximum output of one heater and the sum of the maximum output of that one point and the minimum firing point of the next subsequent heater. Condensation of flue gas products is prevented by monitoring flue exhaust temperature for each heater and controlling the modulation of each heater to maintain a minimum heater output sufficiently high to prevent condensation of flue gas products from that heater. Rapid reaction to changes in system heat demand is provided by sensing changes in flow rate in a primary loop of the system and anticipating resulting changes in temperature thus allowing for change in heater output prior to the time the change in flow rate has fully impacted system temperature.

Abstract: Strain augmented power cycle is disclosed. This power cycle is a thermodynamic power cycle that contains a strain energy device to increase the thermodynamic efficiency above what is possible from a conventional Rankine power cycle. Strain augmented power cycle comprises an assembly of components including a working fluid, a pump, an evaporator, a strain energy device, an expander and a condenser.