Abstract: The invention relates to a method for operating a power plant (1) for generating electrical energy for delivery to at least one consumer (16) by combustion of a carbonaceous combustible, wherein carbon dioxide (19) is separated from the flue gas (7) of the power plant (1), the separated carbon dioxide (19) is converted at least in part into a fuel (20), characterized in that the fuel (20) is combusted at least temporarily in at least one heat engine (4) so as to form a waste gas (8), and electrical energy is generated by the heat engine (4) and is delivered to at least one consumer (16), at least some of the thermal energy of the waste gas (8) being used in at least one of the following processes: a) for heating combustion air (10) of a power plant (1); b) for heating a process medium (14) of the power plant (1); c) in a drying of the combustible of the power plant (1); and d) in carbon dioxide separation.

Abstract: A suction throttling valve adjusts flow of a process gas through an inlet flowline. A compressor pressurizes the process gas. An outlet flowline flows the process gas from the compressor. An anti-surge flowline branching from the outlet flowline directs a first portion of the process gas from the outlet flowline back to the inlet flowline. The anti-surge flowline is connected to the inlet flowline intermediate of the suction throttling valve and the compressor. An anti-surge control valve adjusts flow of the first portion of the process gas through the anti-surge flowline to the inlet flowline. A bypass flowline provides an alternative flow path for a second portion of the process gas flowing through the anti-surge flowline to the inlet flowline around the suction throttling valve. A bypass control valve adjusts flow of the second portion of the process gas through the bypass flowline.

Abstract: A method of suppressing steam production in a HRSG where a volume of feed water is diverted upstream bypassing a portion of the economizer and returning the volume of diverted feed water to a downstream portion of the economizer. A control logic circuit is used to manipulate a suppression control valve regulating the bypassed feed water, thereby reducing the temperature of water in the steam drum. Bypassing feed water flow into a downstream portion of an economizer reduces the steam production rate in the steam drum by increasing the evaporator approach temperature, permitting gas turbines to operate at base load even after an upgrade, by preventing the waste heat boiler from exceeding its rated capacity and pressure.

Abstract: A steam turbine plant and an operating method thereof, and a combined cycle plant and an operating method thereof, include: a turbine; steam supply lines that supply main steam to the turbine; a steam control valve and an intercept valve provided to the steam supply lines; and a first auxiliary steam supply line that supplies auxiliary steam to the turbine via the steam supply lines which are located farther downstream than the steam control valve and the intercept valve.

Abstract: A combined circulating system of a micro gas turbine, a transportation means, and a charging system are provided. The circulating system includes the micro gas turbine, a heat exchange unit, a circulating water tank, a piston engine, and a power generating apparatus, wherein the micro gas turbine is provided with a regenerator; an exhaust port of the regenerator is connected with an air inlet of the heat exchange unit to provide a heat source to the heat exchange unit; the exhaust port of the heat exchange unit is led to atmosphere, a water inlet of the heat exchange unit is connected with a water outlet of the circulating water tank, and a steam outlet of the heat exchange unit is connected with the piston engine to enable high pressure steam to enter the piston engine to push the piston engine to produce work.

Abstract: A first system herein may include: (i) a pumped-heat energy storage system (“PHES system”), wherein the PHES system is operable in a generation mode to convert at least a portion of stored thermal energy into electricity, wherein the PHES system includes a working fluid path circulating a working fluid through, in sequence, at least a compressor system, a hot-side heat exchanger system, a turbine system, a cold-side heat exchanger system, and back to the compressor system; and (ii) a fluid path directing a first fluid through an intercooler and to a power generation plant, and wherein the working fluid path through the compressor system includes circulating the working fluid through, in sequence, at least a first compressor, the intercooler, and a second compressor, and wherein the intercooler thermally contacts the working fluid with the first fluid, transferring heat from the working fluid to the first fluid.

Abstract: A steam generation apparatus includes: a heat medium flow passage through which a heat medium flows; a primary economizer disposed in the heat medium flow passage; a secondary economizer disposed in the heat medium flow passage at an upstream side of the primary economizer with respect to a flow direction of the heat medium; a primary evaporator disposed in the heat medium flow passage at an upstream side of the secondary economizer with respect to the flow direction of the heat medium; a first flash tank for generating flash steam; a first feed water line configured to supply water heated by the primary economizer to the secondary economizer; and a second feed water line disposed so as to branch from the first feed water line and configured to supply the water heated by the primary economizer to the first flash tank.

Abstract: A control device for adjusting an amount of fuel to be supplied to a gas turbine based on a rotational speed of the gas turbine, such that a frequency of electric power output by a power generator that generates electric power using the gas turbine is within a given range, includes a load value acquisition unit configured to acquire a load value that is a value of a load applied to the power generator after cutoff of a part of the load applied to the power generator when the part of the load applied to the power generator is cut off, an arithmetic unit configured to calculate an adjusted value that is a value of the load different from the load value by carrying out an arithmetic operation on the load value and a bias, and a command unit configured to adjust the amount of fuel by outputting a first signal for causing the power generator to output electric power corresponding to the adjusted value.

Abstract: Aircraft power plants including combustion engines, and associated methods for recuperating waste heat from such aircraft power plants are described. A method includes transferring the heat rejected by the internal combustion engine to supercritical CO2 (sCO2) used as a working fluid in a heat engine. The heat engine converts at least some the heat transferred to the sCO2 to mechanical energy to perform useful work onboard the aircraft.

Abstract: A waste heat recovery system including a drive unit, the drive unit having a drive shaft, a compressor, the compressor operably coupled to the drive shaft, wherein operation of the drive unit drives the compressor, and a waste heat recovery cycle, the waste heat recovery cycle coupled to the drive unit and the compressor, wherein a waste heat of the drive unit powers the waste heat recovery cycle, such that the waste heat recovery cycle transmits a mechanical power to the compressor, is provided. Furthermore, an associated method is also provided.

Abstract: An arrangement for storing energy, the arrangement comprising a heat-charging mass (4) and a heat-transfer channeling (3), the arrangement also comprising a heating member (11) adapted to heat up the heat-charging mass (4). The arrangement comprises a boiler belonging to a discarded combustion power plant and converted to a thermal energy storage (2) by at least partly filling the boiler with the heat-charging mass (4).

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: Methods and systems for generating power (and optionally heat) from a high value heat source using a plurality of circulating loops comprising a primary heat transfer loop, several power cycle loops and an intermediate heat transfer loop that transfers heat from the high-temperature heat transfer loop to the several power cycle loops.

Abstract: Disclosed is a hybrid power generation facility.

Abstract: Control systems and methods suitable for combination with power production systems and methods are provided herein. The control systems and methods may be used with, for example, closed power cycles as well as semi-closed power cycles. The combined control systems and methods and power production systems and methods can provide dynamic control of the power production systems and methods that can be carried out automatically based upon inputs received by controllers and outputs from the controllers to one or more components of the power production systems.

Abstract: Apparatus, systems, and methods store energy by liquefying a gas such as air, for example, and then recover the energy by regasifying the liquid and combusting or otherwise reacting the gas with a fuel to drive a heat engine. The process of liquefying the gas may be powered with electric power from the grid, for example, and the heat engine may be used to generate electricity. Hence, in effect these apparatus, systems, and methods may provide for storing electric power from the grid and then subsequently delivering it back to the grid.

Abstract: The present disclosure describes methods and systems for generating electricity. A method of generating electricity can include evaporating water with a low grade heat source to form low-temperature steam. The low-temperature steam can be superheated to a superheated temperature by transferring heat to the low-temperature steam from a thermal energy storage that is at a temperature higher than the superheated temperature. A steam turbine generator can be powered with the superheated steam to generate electricity. The thermal energy storage can be recharged using electricity from an intermittent electricity source.

Abstract: A gas turbine exhaust heat recovery plant includes a plurality of gas turbine exhaust heat recovery devices that have a gas turbine and an exhaust heat recovery boiler for generating steam by recovering exhaust heat of the gas turbine, a steam-utilizing facility that utilizes the steam generated by the exhaust heat recovery boiler, and an inter-device heat medium supply unit capable of supplying a portion of water heated or a portion of the steam generated by at least one of the gas turbine exhaust heat recovery devices out of the plurality of gas turbine exhaust heat recovery devices, to the other gas turbine exhaust heat recovery device.

Abstract: A CCPP includes a gas turbine, a HRSG, a steam turbine a flash tank and first and second supply lines. The gas turbine, the HRSG and the steam turbine are interconnected to generate power. The gas turbine may include an air preheating system to preheat the air supplied in the gas turbine to enable expedite combustion therein. The flash tank is fluidically connected at a cold end of the HRSG to extract waste hot water from the cold end. Further, the first supply line is configured to interconnect the flash tank and the steam turbine to supply of flash steam to the steam turbine. Furthermore, the second supply line is configured to interconnect the flash tank and the air preheating system to supply hot flash condensate thereto.

Abstract: A power generation system includes a combustion system, a liquid supply system, and a vapor supply system. The combustion system is configured to generate power by combusting an alternative fuel. The liquid supply system is configured to channel a liquid alternative fuel to the combustion system. The vapor supply system is configured to channel a vapor alternative fuel to the combustion system. The combustion system is ignited by combusting the liquid alternative fuel from the liquid supply system and is operated by combusting the vapor alternative fuel from the vapor supply system.

Abstract: Waste heat management systems are described. The waste heat management systems include a turbine engine having a compressor section, a combustor section, a turbine section, and a nozzle. The compressor section, the combustor section, the turbine section, and the nozzle define a core flow path that expels through the nozzle. The waste heat management systems also include an auxiliary power unit (APU) system and a waste heat recovery system operably connected to the APU system. The APU system is integrated into a working fluid flow path of the waste heat recovery system.

Abstract: Supercritical fluid systems and aircraft power systems are described. The systems include a compressor, a turbine, and a generator. A primary working fluid flow path has a primary working fluid that passes through the compressor, a separator, the turbine, and back to the compressor. A secondary working fluid flow path having a secondary working fluid that passes through the generator, the compressor, the separator, and back to the generator. The primary working fluid and the secondary working fluid are compressed and mixed within the compressor to form a mixture of the two fluids and the separator separates the mixture of the two fluids to direct the primary working fluid back to the turbine and the secondary working fluid to the generator.

Abstract: A system includes a first working fluid compressor configured to pressurize a working fluid, and a prime mover coupled to the first working fluid compressor and configured to provide a mechanical input into the first working fluid compressor. An exhaust assembly is coupled to the prime mover and is configured to receive exhaust heat from the prime mover, the exhaust assembly including a generator configured to generate electric current based on the exhaust heat received by the exhaust assembly. A second working fluid compressor includes an electric motor electrically and synchronously coupled to the generator and configured to pressurize the working fluid.

Abstract: A power production facility comprises a power plant that combusts fuel to produce energy for generating electricity and exhaust gas, an emissions capture unit to receive the exhaust gas to remove pollutants, a fuel cell to generate electricity via reaction of constituents and provide byproduct heat to operate the emissions capture unit, and an electrolyzer to generate constituents for the fuel cell from water byproduct received from the fuel cell resulting from the reaction process. A method of generating power with an emissions capture unit comprises providing a hybrid power plant configured to generate hydrogen gas and oxygen gas with an electrolyzer from a water input using an electrical input, generate electricity, heat and the water input with a fuel cell from the hydrogen gas and oxygen gas of the electrolyzer, and capture emissions from exhaust gas with an emissions capture unit using the heat from the fuel cell.

Abstract: Operating coal fired energy systems. A method of operating a coal fired energy system comprises operating a coal fired steam generator comprising a coal feed system and a main air feed system to provide a coal-air mixture as a heating source for a boiler for generating steam. The method includes operating an auxiliary air compression system comprising a fueled engine coupled to a compressor for providing an auxiliary supply of compressed air to a soot blower of the coal-fired steam generator. The method comprises injecting the auxiliary supply of compressed air along walls of the boiler to remove soot and ash buildup from the boiler.

Abstract: There are provided a gas turbine system and a gas turbine power generator that can achieve an increase in output power and a decrease in fuel efficiency together and curb an increase in cost and weight. There is also provided a gas turbine system that can stably supply a necessary amount of air to a combustor even when a compressor and a turbine on one side are stopped. The gas turbine system 1 includes a plurality of gas turbine units 2 and 3, a single combustor 4, a plurality of pipes 5, a plurality of on-off valves 6, and a control unit 7. In a first operation mode, the control unit 7 controls switching-on/off of the on-off valves 6 such that air is supplied to the combustor 4 from a first compressor 21 and a second compressor 31.

Abstract: A non-positive displacement type pressurizing device for pressurizing a fluid includes a rotor including a rotary blade row including a plurality of rotary blades provided at intervals in a circumferential direction; a casing that accommodates the rotor; a stationary blade row supported by the casing and including a plurality of stationary blades provided at intervals in the circumferential direction; and a plurality of heat exchanging units for cooling the fluid, wherein the heat exchanging units are configured to divide a flow path formed between stationary blades, of the plurality of stationary blades, adjacent to one another in the circumferential direction in a height direction of the stationary blades.

Abstract: A combined cycle plant includes: a gas turbine having a compressor, a combustor, and a turbine; a supplementary firing burner configured to raise a temperature of an exhaust gas of the gas turbine; a heat recovery steam generator configured to generate a steam using an exhaust heat of the exhaust gas; a steam turbine configured to be driven by the steam generated by the heat recovery steam generator; and a control device configured to change both an output of the combustor and an output of the supplementary firing burner when an output of the combined cycle plant is to be changed.

Abstract: Methods and systems for treating a subterranean formation. An example method performs a wellbore operation with a first treatment fluid, removes a flammable gaseous hydrocarbon from a well penetrating the subterranean formation; wherein the well is disposed on a wellsite, introduces the flammable gaseous hydrocarbon into a gas-to-liquid reactor located on the wellsite to produce an oleaginous liquid, produces a second treatment fluid comprising the oleaginous liquid at the wellsite, and introduces the second treatment fluid into the well.

Abstract: In a one embodiment, a gas turbine system that includes a first pump that supplies distillate fuel to a combustor. A second pump that supplies fuel oil to the combustor. A fuel selection unit that controls a first flow of distillate fuel and a second flow of fuel oil to the combustor. A controller that receives feedback from a sensor and in response to the feedback from the sensor controls the fuel selection unit to start the gas turbine system on the fuel oil.

Abstract: A first system herein may include: (i) a pumped-heat energy storage system (“PHES system”), wherein the PHES system is operable in a generation mode to convert at least a portion of stored thermal energy into electricity, wherein the PHES system includes a working fluid path circulating a working fluid through, in sequence, at least a compressor system, a hot-side heat exchanger system, a turbine system, a cold-side heat exchanger system, and back to the compressor system; and (ii) a fluid path directing a first fluid through an intercooler and to a power generation plant, and wherein the working fluid path through the compressor system includes circulating the working fluid through, in sequence, at least a first compressor, the intercooler, and a second compressor, and wherein the intercooler thermally contacts the working fluid with the first fluid, transferring heat from the working fluid to the first fluid.

Abstract: A combined cycle power generation system for an aircraft includes fuel cell and supercritical CO2 cycles. The fuel cell cycle includes a compressor and turbine disposed on a first shaft, a fuel cell in fluid communication with the compressor and a fuel source, and a combustor in fluid communication with the fuel cell and the turbine. The combustor is configured to combust partially spent fuel from the fuel cell and produce combustion exhaust gas for delivery to the turbine. The supercritical CO2 cycle includes a compressor and turbine disposed on a second shaft, a supercritical CO2 fluid circuit in thermal communication with the combustor and configured to deliver CO2 to the turbine and compressor, and a heat exchanger in thermal communication with the supercritical CO2 fluid circuit and a source of cooling fluid. A mechanical linkage is configured to transfer power from the second shaft to the first shaft.

Abstract: A gas turbine engine includes a fan bypass ratio greater than 12. A speed reduction device includes a gear ratio of at least 2.6. A turbine section includes a transition duct that is located between a high pressure turbine and a low pressure turbine and includes fewer support struts than vanes in a first vane row of the low pressure turbine.

Abstract: Provided is a combined cycle (CC) unit standby system with integrated auxiliary gas turbine generator (Aux. GT), including: a plurality of first gas turbines, a plurality of heat recovery boilers, a steam turbine, a condenser, at least a second gas turbine generator and a control unit. As such, the present invention incorporates at least a second gas turbine generator of small capacity into the CC unit standby system, the pipelines and components of each unit are kept in a hot state, to facilitate the rapid load increase during restart process, to save energy during the standby period, accelerate the restart process and reduce the energy consumption during the starting phase, and also keep the unit in “House Load Operation” state, stay independent from the power grid to cope with the emergency situation of black start, improve the restart and energy efficiency in standby and shutdown states.

Abstract: A method for operating a flue gas purification system, comprising, in the flue gas purification system, equipped with a boiler which can burn oil fuel and coal fuel either simultaneously or switching therebetween, a denitration equipment having a reducing agent injector and a catalytic reactor, an inlet flue to guide flue gas discharged from the boiler to the denitration equipment, an outlet flue to guide flue gas discharged from the denitration equipment, a bypass flue which can guide flue gas from the inlet flue to the outlet flue so as to bypass the denitration equipment, and a bypass damper, opening the bypass damper and burning oil fuel in the boiler being in condition not yet suitable for coal combustion to allow the flue gas discharged from the boiler to dividedly flow to the denitration equipment and the bypass flue, switching the oil fuel to coal fuel when the boiler is in condition suitable for coal combustion to burn the coal fuel in the boiler, closing the bypass damper after switching the oil fue

Abstract: A power plant can comprise a gas turbine productive of an exhaust gas, a steam turbine, a heat recovery steam generator that extracts heat from gas turbine exhaust gas and supplies fluid to the steam turbine, a thermal storage unit storing a thermal storage working medium that is configured to discharge thermal energy into the fluid supplied from the heat recovery steam generator to supplement power generation by the steam turbine, a first heat exchanger disposed within the heat recovery steam generator to transfer thermal energy from the exhaust gas to the thermal storage working medium, and a second heat exchanger in flow communication with the heat recovery steam generator and the thermal storage unit, the second heat exchanger facilitating a direct heat transfer of thermal energy from the thermal storage working medium in the thermal storage unit to the fluid supplied from the heat recovery steam generator.

Abstract: A steam turbine system (200) includes a steam turbine (60) in which a main flow path (C) through which a main steam flows is formed, and a saturated steam generation portion (210) that is configured to generate a saturated steam. The saturated steam generation portion (210) is configured to feed the saturated steam into a wet region (C1) in which the main steam in the main flow path (C) is in a wet state via a hollow portion formed inside a stator vane (650) of the steam turbine (60). The stator vane (650) has a plurality of supply ports that are formed such that the hollow portion is configured to communicate with the main flow path (C), and a discharge amount of the saturated steam increases from an inner circumferential side toward an outer circumferential side in a blade height direction.

Abstract: A gas turbine engine is defined wherein the inlet guide vanes leading into a core engine flow path are sized and positioned such that flow paths positioned circumferentially intermediate the vane are sufficiently large that a hydraulic diameter of greater than or equal to about 1.5 is achieved. This will likely reduce the detrimental effect of icing.

Abstract: A combined cycle power plant that includes a gas turbine engine, a heat recovery steam generator (HRSG), a steam turbine, a primary condenser, a condensate extraction pump, a gland steam condenser, and a cooling module. The HRSG generates steam. The steam turbine receives steam from the HRSG. The primary condenser is fluidly coupled to the steam turbine and receives a first portion of exhaust steam from the steam turbine. The condensate extraction pump is fluidly coupled to the primary condenser and receives a condensed first portion of exhaust steam. The gland steam condenser is fluidly coupled to the steam turbine and receives a second portion of exhaust steam from the steam turbine. The cooling module is fluidly coupled to the gland steam condenser and supplies a cooling fluid to the gland steam condenser. The cooling module is fluidly isolated from the condensate extraction pump.

Abstract: A combined cycle power plant that includes a first gas turbine engine including a first turbine section, a second gas turbine engine including a second turbine section having an aft outlet configured to discharge an exhaust gas stream, an emissions reduction system configured to receive the exhaust gas stream discharged from the second gas turbine engine, and configured to remove oxides of nitrogen from the exhaust gas stream, and an interstage extraction system communicatively coupled with the first turbine section. The interstage extraction system is configured to selectively extract turbine extraction air from the first turbine section for providing heat to the emissions reduction system.

Abstract: A floating vessel equipped with a power plant includes a hull and a process deck arranged on a portion of the hull above compartments within the hull. The power plant includes a fuel source and at least one electrical power generator driven by a gas turbine; the fuel source arranged for providing fuel to the gas turbine. Per gas turbine, the floating vessel is equipped with a steam production unit coupled to the gas turbine exhaust for receiving heat to produce pressurized steam. Per each steam production unit, the floating vessel is equipped with at least one secondary power generator driven by a steam turbine, which is coupled to the steam production unit for receiving steam. Each gas turbine and steam production unit are positioned on the process deck, and each secondary power generator and steam turbine are positioned under the process deck in the one or more compartments.

Abstract: A gas turbine engine that includes an inlet volume flow control appliance and methods of operating the same are provided. The method includes operating the gas turbine engine with the inlet volume flow control appliance supplying a compressor inlet volume flow that is below a maximum compressor inlet volume flow. A mass flow of a liquid agent is added to a compressor gas mass flow while the gas turbine engine is operated with a compressor inlet volume flow below a maximum compressor inlet volume flow. The mass flow of a liquid agent may be controlled as a function of the pitch of variable inlet guide vanes. The method further comprises adjusting the volume flow control appliance to increase the compressor inlet volume flow and increasing the mass flow of liquid agent added to the compressor gas mass flow while the inlet volume flow control appliance increases the compressor inlet volume.

Abstract: A system for repowering a coal fired electrical generation plant with natural gas is disclosed. The plant has having high and low pressure steam turbines that drives an electrical generator. The coal fired plant has a regenerative system comprising a plurality of feedwater heaters that supply heated feedwater to evaporators and superheaters that supply steam to the turbines. The repowering system has a gas turbine that drives a second electrical generator where the HRSG is configured to receive the exhaust from the gas turbine and which is heated by a burner so as to generate steam for driving the steam turbines. The feedwater heaters utilize condensate from the said and from steam extractions to supply heated feedwater to the superheaters that feed superheated steam to turbines such that the first generator driven by the turbines is driven at a high percentage of its rated megawatt output.

Abstract: A plant according to an embodiment includes a gas turbine; a heat recovery unit that includes a primary heat recovery steam generator in which a primary heat exchanging unit generates primary steam by exchanging heat that is the thermal energy of the flue gas from the gas turbine, and a secondary heat recovery steam generator that is installed independently from the primary heat exchanging unit, and in which a secondary heat exchanging unit generates secondary steam by exchanging heat that is the thermal energy of the flue gas partly having exchanged heat in the primary heat exchanging unit included in the primary heat recovery steam generator; a primary steam turbine; a CO2 recovery unit; and a first reboiler heat supply line.

Abstract: A gas turbine system includes a gas turbine and a water circuit. The water circuit includes a supply line fluidly coupling the low pressure economizer to a low pressure water supply. A connection line fluidly couples the low pressure evaporator to the low pressure economizer. A bypass supply line extends between the connection line and a heat exchanger. A bypass return line extends from the heat exchanger and includes a first return branch and a second return branch. The first return branch extends to the supply line. The second return branch extends to the connection line. At least one first diverter valve disposed on the bypass return line. The at least one first diverter valve operable to direct the flow of water towards one or both of the supply line and the connection line.

Abstract: In one embodiment, a plant control apparatus controls a power plant. The plant includes a gas turbine, a generator driven by the gas turbine, an exhaust heat recovering boiler to generate first steam by using heat of exhaust gas from the gas turbine, a first steam turbine driven by the first steam, a reheater provided in the boiler and configured to heat exhaust steam from the first steam turbine by the exhaust gas to generate reheat steam, and a second steam turbine driven by the reheat steam. The apparatus includes a first warming-up module to supply second steam from equipment different from the boiler to the first steam turbine to warm up this turbine, before this turbine is started. The apparatus further includes a second warming-up module to supply the second steam to the reheater to warm up the reheater, before the first steam turbine is started.

Abstract: A gas turbine plant includes a gas turbine, an exhaust heat recovery boiler, and a water supply system that is configured to supply water to the exhaust heat recovery boiler. The exhaust heat recovery boiler has an evaporator configured to use an exhaust gas to heat water, thereby generating steam, and a reheater that is configured to heat steam with the exhaust gas introduced from the evaporator. The water supply system has a water supply line that is configured to supply water from a water supply source to the exhaust heat recovery boiler, and a supplied water temperature regulator that is configured to regulate a temperature of supplied water, which is the water in the water supply line.

Abstract: A power plant system can comprise a first gas turbine having a first efficiency to produce a first exhaust flow, a first electrical generator driven by the first gas turbine, a first heat recovery steam generator to receive the first exhaust flow and generate a first steam flow, a second gas turbine having a second efficiency less than the first efficiency to produce a second exhaust flow, a second electrical generator driven by the second gas turbine, and an exhaust gas conditioning device to reduce temperature of the second exhaust flow, a steam turbine driving a steam electrical generator to receive the first steam flow. The second gas turbine can be selectively operated to generate electricity with the second electrical generator under peak loading conditions when a sum of output from the steam electrical generator and the first electrical generator are less than an electrical demand from a grid.

Abstract: A dryer apparatus is disclosed comprising a container having a container inlet and outlet, a pump that is configured to motivate a first air-vapor mixture flow via the container inlet and via the container outlet, a heating device configured to heat the first air-vapor mixture, a selector with at least two states, a compressor that is configured to compress and motivate a part of the first air-vapor mixture flow as a second air-vapor mixture flow, to flow through a first heat exchanger and to flow through a second heat exchanger and a pressure reducing device that is configured to reduce the pressure of said second air-vapor mixture downstream said first heat exchanger. The selector is configured to direct most of the first air-vapor mixture to flow in a closed cycle through the container, or configured to exchange most of the first air-vapor mixture with air located outside the apparatus.

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.