A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
H02J 3/18 - Arrangements for adjusting, eliminating or compensating reactive power in networks
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
A power production facility comprises a combined cycle power plant comprising a gas turbine engine configured to combust a fuel to produce a gas that can be used to produce rotational shaft power for generating electricity and a steam system configured to produce steam with the gas, and a vapor separation membrane positioned in the gas to separate water vapor from the gas. A method of recovering water from a gas turbine combined cycle power plant comprises operating a gas turbine engine to produce electrical power with a gas, generating steam from a water supply with the gas using a steam system, capturing water vapor from the gas to produce captured water using a water vapor separation membrane, and returning at least a portion of the captured water to the water supply.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01K 11/02 - Steam engine plants characterised by the engines being structurally combined with boilers or condensers the engines being turbines
A distribution system for injecting reductant into an exhaust duct of a power plant comprises a first injection grid comprising a first manifold and a first plurality of distribution branches, and a second injection grid comprising a second manifold and a second plurality of distribution branches, wherein the first plurality of distribution branches is interleaved with the second plurality of distribution branches, and the first plurality of distribution branches and the second plurality of distribution branches each receive reductant flow from their respective manifold in opposite directions. A method for injecting a reductant into an exhaust comprises generating a first mass flow gradient of reductant along a first axis, generating a second mass flow gradient of reductant along a second axis, wherein the mass flow gradients decrease in directions along their axes, wherein the first direction and the second direction are disposed in a counterflow arrangement.
F01N 3/20 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust characterised by methods of operationControl specially adapted for catalytic conversion
A hydrogen production system comprises a hydrogen production facility comprising electrolyzer units, a controller in communication with the hydrogen production facility, and memory having instructions stored therein executable by the controller to operate the hydrogen production facility, the instructions comprising receiving an instruction signal indicating an available power level, determining availability states of electrolyzer units in the hydrogen production facility to determine a number of available electrolyzer units, determining an available load at which each of the available electrolyzer units is capable of operating relative to a base load, determining a base group of available electrolyzer units having available loads available to consume less than the available power level, determining a trim group of available electrolyzer units to consume any remaining power of the available power level not consumed by the base group of available electrolyzer units, and operating electrolyzer units to produce hydrogen.
Systems and techniques may generally be used for providing an advisory or action regarding a fault or alert for an industrial power generation system. An example technique may include receiving a set of sensor data and identifying an alert related to a subsystem of the industrial power generation system. The example technique may include predicting a root cause of the alert using a similarity match evaluation or using a machine learning trained model for at least one expected value and an actual value from the set of sensor data. The example technique may include determining, based on the predicted root cause, a recommended action and outputting the recommended action.
A power plant comprises a steam system, a first electrolyzer, a heat storage system, and a heat exchanger configured to exchange thermal energy between the steam system, the first electrolyzer and the heat storage system. A method of operating an electrolyzer in a combined cycle power plant comprises operating a steam system to convert water to steam, operating an electrolyzer in a standby mode, the electrolyzer configured to convert water and electricity to hydrogen and oxygen when the electrolyzer is in an operating mode, circulating water from the steam system through a heat exchanger, circulating a first heat transfer medium between the electrolyzer and the heat exchanger, and circulating a second heat transfer medium between the heat exchanger and a thermal storage container.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
H02J 3/18 - Arrangements for adjusting, eliminating or compensating reactive power in networks
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
H02J 3/18 - Arrangements for adjusting, eliminating or compensating reactive power in networks
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
A medical sealant applicator device for delivery of a multi-component sealant including a first body having a base, a first syringe plunger, a second syringe plunger, and a longitudinal channel, laterally interposed between the first syringe plunger and the second syringe plunger. Each of the first syringe plunger and the second syringe plunger is oriented to extend in a first direction from the base. The first syringe plunger has a first free end having a first proximal plunger piston. The second syringe plunger having a second free end having a second proximal plunger piston. A second body of the medical sealant application device has a first syringe chamber, a second syringe chamber, and a longitudinal fluid chamber laterally interposed between the first syringe chamber and the second syringe chamber. The longitudinal fluid chamber has a proximal end and a distal end.
A system for drying hydrogen in a hydrogen production facility comprises an electrolyzer for producing a flow of hydrogen gas, a drying device configured to remove moisture from the flow of hydrogen gas, a compressor configured to receive the flow of hydrogen gas from the drying device, and a recirculation line connected to output of the compressor to recirculate at least a portion of the flow of hydrogen gas from the compressor to the drying device. A method of drying hydrogen in a hydrogen production facility comprises producing a flow of hydrogen gas with an electrolyzer, drying the flow of hydrogen gas with a drying device, compressing the flow of hydrogen gas from the drying device with a compressor, and recirculating at least a portion of the flow of hydrogen gas from the compressor to the drying device to maintain pressure distribution within the drying device.
A power plant comprises a steam system, a first electrolyzer, a heat storage system, and a heat exchanger configured to exchange thermal energy between the steam system, the first electrolyzer and the heat storage system. A method of operating an electrolyzer in a combined cycle power plant comprises operating a steam system to convert water to steam, operating an electrolyzer in a standby mode, the electrolyzer configured to convert water and electricity to hydrogen and oxygen when the electrolyzer is in an operating mode, circulating water from the steam system through a heat exchanger, circulating a first heat transfer medium between the electrolyzer and the heat exchanger, and circulating a second heat transfer medium between the heat exchanger and a thermal storage container.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
A combined cycle power plant comprises a gas turbine engine comprising a compressor to produce compressed gas, a combustor to produce combustion gas from compressed gas and fuel, and a turbine to receive combustion gas to produce rotational shaft power; a steam system generates steam from water using the combustion gas exiting the turbine; a first stage fuel-gas heater receives the fuel before entering the combustor and receive feedwater from the steam system to transfer heat from the feedwater to the fuel; and a second stage fuel-gas heater receives at least a portion of the fuel from the first stage fuel-gas heater to transfer heat to the fuel from a heat transfer medium before the fuel enters the combustor. A method comprises operating a gas turbine engine, operating a steam cycle, extracting compressed air for cooling the gas turbine engine, and transferring heat to fuel from the compressed air.
F02C 7/224 - Heating fuel before feeding to the burner
F02C 6/08 - Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output providing compressed gas the gas being bled from the gas-turbine compressor
F02C 7/18 - Cooling of plants characterised by cooling medium the medium being gaseous, e.g. air
A power plant comprises supplies of hydrogen fuel, oxygen fuel and water, a boiler comprising a burner for combusting hydrogen and oxygen to produce heat, combustion products and low/intermediate-pressure steam and a first heat exchanger configured to heat water to generate high-pressure steam, and a steam turbine comprising a first turbine configured to be driven only with the high-pressure steam to provide input to a first electrical generator and a second turbine configured to be driven by low/intermediate-pressure steam from the boiler. A method of operating a steam plant comprises combusting hydrogen fuel in a boiler to produce combustion products and LP/IP steam, turning a turbine with the combustion products, condensing water from the combustion products in a condenser, heating water from the condenser in a heat exchanger within the boiler to produce HP steam and turning a turbine with the steam from the first heat exchanger.
F01K 25/00 - Plants or engines characterised by use of special working fluids, not otherwise provided forPlants operating in closed cycles and not otherwise provided for
F01K 3/20 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters with heating by combustion gases of main boiler
F01K 3/26 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters with heating by steam
F01K 7/18 - Steam engine plants characterised by the use of specific types of enginePlants or engines characterised by their use of special steam systems, cycles or processesControl means specially adapted for such systems, cycles or processesUse of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type the turbine being of multiple-inlet-pressure type
F01K 9/00 - Steam engine plants characterised by condensers arranged or modified to co-operate with the engines
A battery system for storing electric energy on a grid system comprises a stationary energy storage facility comprising a first bank of batteries comprising a first plurality of batteries of a first type, wherein the first type comprises stationary storage batteries, a local power conversion system for receiving output of the first plurality of batteries and outputting power to the grid system, and a local controller for integrating and operating the local power conversion system with the first bank of batteries; an augmentation battery system comprising a second bank of batteries comprising a second plurality of batteries of a second type, wherein the second type of batteries comprises electric vehicle batteries, a secondary power conversion system for receiving output of the second plurality of batteries and outputting power to the local power conversion system, and a battery management system for operating the second bank of batteries, the battery management system comprising part of the electric vehicle batteries; and a translation battery management system configured to translate communications of the pack battery management system for communicating with the local controller.
A battery energy storage system comprises a first equipment unit comprising a first skid positionable on a surface, a first inverter and a first transformer mounted on the first skid, a second equipment unit comprising a second skid, a second inverter and a second transformer mounted on the second skid, and a support structure for positioning the second equipment unit longitudinally above and spaced apart from the first equipment unit in a laterally offset manner. A method of increasing energy storage capacity of a storage system comprises building a support structure over a first inverter and transformer unit installed at a first location, placing a second inverter and transformer unit on the support structure such that the second inverter and transformer unit is longitudinally spaced from and laterally offset from the first inverter and transformer unit and adding an additional battery container.
A utility-scale energy storage and conversion system can operate two or more inverter groups such that their reactive power commands are proportional to their available reactive power range. The control system can therefore distribute the reactive power commands in proportion to the available Q range, thereby ensuring that all inverters in the utility-scale energy storage and conversion system 100 operate with the same Q “headroom”. In addition, the utility-scale energy storage and conversion system can use an on-load tap changer (LTC) to adjust a terminal voltage associated with a first group of inverters and a second group of inverters. The first group of inverters can be associated with a first rating and the second group of inverters can be associated with a second rating that is greater than the first rating.
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02M 7/539 - Conversion of DC power input into AC power output without possibility of reversal by static converters using discharge tubes with control electrode or semiconductor devices with control electrode using devices of a triode or transistor type requiring continuous application of a control signal using semiconductor devices only, e.g. single switched pulse inverters with automatic control of output wave form or frequency
A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
A combined-cycle power plant comprises a gas turbine engine for generating exhaust gas, an electric generator driven by the gas turbine engine, a steam generator receiving the exhaust gas to heat water and generate steam, and a duct burner system configured to heat exhaust gas in the steam generator before generating the steam and that comprises a source of hydrogen fuel, a fuel distribution manifold to distribute the hydrogen fuel in a duct of the steam generator, and an igniter to initiate combustion of the hydrogen fuel in the exhaust gas. A method for heating exhaust gas in a steam generator for a combined-cycle power plant comprises directing combustion gas of a gas turbine engine into a duct, introducing hydrogen fuel into the duct, combusting the hydrogen fuel and the combustion gas to generate heated gas, and heating water in the duct with the heated gas to generate steam.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01K 23/06 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
F01K 25/00 - Plants or engines characterised by use of special working fluids, not otherwise provided forPlants operating in closed cycles and not otherwise provided for
F23D 14/10 - Premix gas burners, i.e. in which gaseous fuel is mixed with combustion air upstream of the combustion zone induction type, e.g. Bunsen burner with elongated tubular burner head
F23D 14/22 - Non-premix gas burners, i.e. in which gaseous fuel is mixed with combustion air on arrival at the combustion zone with separate air and gas feed ducts, e.g. with ducts running parallel or crossing each other
F23R 3/20 - Flame stabilising means, e.g. flame holders for after-burners of jet-propulsion plants incorporating fuel injection means
09 - Scientific and electric apparatus and instruments
11 - Environmental control apparatus
Goods & Services
Electrolysis machines for generating hydrogen Hydrogen production equipment, namely, transformers and rectifiers Hydrogen production equipment, namely, gas separators for the cleaning and purification of gases
A power production facility comprises a combined cycle power plant comprising a gas turbine engine configured to compress air for combustion with a fuel in a combustor to produce exhaust gas that can be used to produce rotational shaft power for generating electricity and a steam system configured to produce steam from water with the exhaust gas to rotate a steam turbine for generating additional electricity, an electrolyzer configured to generate H2 and O2, wherein the electrolyzer is configured to provide the H2 to the combustor for combustion and the O2 to portions of the gas turbine engine, and a heat exchanger configured to receive the O2 and fluid from the steam system and to heat the O2 before passing the O2 into portions of the gas turbine engine.
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.
F02C 3/34 - Gas-turbine plants characterised by the use of combustion products as the working fluid with recycling of part of the working fluid, i.e. semi-closed cycles with combustion products in the closed part of the cycle
F01D 13/02 - Working-fluid interconnection of machines or engines
F01D 15/10 - Adaptations for driving, or combinations with, electric generators
F02C 6/10 - Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output supplying working fluid to a user, e.g. a chemical process, which returns working fluid to a turbine of the plant
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
23.
INVERTER TERMINAL VOLTAGE ADJUSTMENT IN POWER SYSTEM
A utility-scale energy storage and conversion system can operate two or more inverter groups such that their reactive power commands are proportional to their available reactive power range. The control system can therefore distribute the reactive power commands in proportion to the available Q range, thereby ensuring that all inverters in the utility-scale energy storage and conversion system 100 operate with the same Q "headroom". In addition, the utility-scale energy storage and conversion system can use an on-load tap changer (ETC) to adjust a terminal voltage associated with a first group of inverters and a second group of inverters. The first group of inverters can be associated with a first rating and the second group of inverters can be associated with a second rating that is greater than the first rating.
A utility-scale energy storage and conversion system can operate two or more inverter groups such that their reactive power commands are proportional to their available reactive power range. The control system can therefore distribute the reactive power commands in proportion to the available Q range, thereby ensuring that all inverters in the utility-scale energy storage and conversion system 100 operate with the same Q “headroom”. In addition, the utility-scale energy storage and conversion system can use an on-load tap changer (LTC) to adjust a terminal voltage associated with a first group of inverters and a second group of inverters. The first group of inverters can be associated with a first rating and the second group of inverters can be associated with a second rating that is greater than the first rating.
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02M 7/539 - Conversion of DC power input into AC power output without possibility of reversal by static converters using discharge tubes with control electrode or semiconductor devices with control electrode using devices of a triode or transistor type requiring continuous application of a control signal using semiconductor devices only, e.g. single switched pulse inverters with automatic control of output wave form or frequency
A hydrogen production system can include one or more hydrogen electrolyzers; a plurality of gas separation units in fluid communication with the one or more hydrogen electrolyzers, wherein at least one gas separation unit of the plurality of gas separation units is spaced laterally apart from an adjacent gas separation unit of the plurality of gas separation units by a first distance greater than a width of one of the one or more hydrogen electrolyzers; and electrical support hardware in electrical communication with the one or more hydrogen electrolyzers and the plurality of gas separation units.
A power plant comprises a combustor for combusting first and second constituents to generate a gas stream, a turbine for rotation by the gas stream, a compressor to receive a first portion of the gas stream and provide compressed gas to the combustor, a recompressor configured to receive a second portion of the gas stream and provide compressed gas to the combustor, a generator to be driven by the turbine, and a methane reforming reactor configured to dry reform methane to provide the first constituent. A method of operating a power plant comprises operating a supercritical CO2 power cycle to turn a turbine, driving a generator with the turbine, extracting CO2 byproduct from the power cycle, reacting fuel and CO2 to produce a synthesis gas in a dry reforming of methane reactor, and mixing the synthesis gas with oxygen to execute a combustion process for the power cycle.
F02C 3/34 - Gas-turbine plants characterised by the use of combustion products as the working fluid with recycling of part of the working fluid, i.e. semi-closed cycles with combustion products in the closed part of the cycle
F02C 3/04 - Gas-turbine plants characterised by the use of combustion products as the working fluid having a turbine driving a compressor
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
F02C 3/24 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products the fuel or oxidant being liquid at standard temperature and pressure
A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.
F02C 6/00 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use
F02C 3/20 - Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
H02J 3/32 - Arrangements for balancing the load in a network by storage of energy using batteries with converting means
H02J 3/18 - Arrangements for adjusting, eliminating or compensating reactive power in networks
28.
Combined-cycle power plant with thermal energy storage
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.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01K 7/16 - Steam engine plants characterised by the use of specific types of enginePlants or engines characterised by their use of special steam systems, cycles or processesControl means specially adapted for such systems, cycles or processesUse of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
F01K 3/26 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters with heating by steam
F02C 6/14 - Gas-turbine plants having means for storing energy, e.g. for meeting peak loads
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.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01K 3/08 - Use of accumulators, the plant being specially adapted for a specific use
30.
Diversion systems for low emission start converter
An emission reduction system for a combined cycle power plant including a gas turbine and heat recovery steam generator (HRSG) can comprise a stationary emission converter in fluid communication with and disposed upstream of the HRSG, and a diversion system operably coupled to an exhaust passage of the gas turbine, the exhaust passage defining an exhaust path for exhaust gas of the gas turbine through the heat recovery steam generator, the diversion system operable to define a primary exhaust path excluding the stationary emission converter and a start-up exhaust path including the stationary emission converter.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
A gas turbine engine rotor assembly comprises a torque tube, turbine stage and stiffening mass. The torque tube comprises a shaft extending from a forward location to an aft end, and a shaft fastening flange disposed at the aft end. The turbine stage comprises a disc, a disc adapter extending forward from the disc, and a disc fastening flange extending from the disc adapter and couplable to the shaft fastening flange at an interface. The stiffening mass is positioned proximate the interface to reduce operational stress in the torque tube. A method of reducing operational stress in a rotor assembly comprises de-stacking a rotor stack, separating a first stage rotor disc adapter from a torque tube, attaching a stiffening mass to an inner diameter of one or both of the disc adapter and the torque tube, attaching the disc adapter to the torque tube, and re-stacking the rotor stack.
A waste water processing system includes an upflow contacting column having a flue gas input for receiving flue gas having a temperature of at least 500 degrees F., a waste water input, and a flue gas output. The waste water input is coupled to a fluid injector, e.g., atomizing nozzles, positioned in the throat of a Venturi portion of the upflow contacting column or in a sidewall of the throat of the Venturi portion of the upflow contacting column. The flue gas in the upflow contacting column has a high velocity, e.g., a gas velocity exceeding 65 fps in the throat of the Venturi portion of the upflow contacting column at a position where the fluid injector is located. Drying additives such as recycled ash, lime, and/or cement may be, and sometimes are, input into the upflow contacting column downstream of the waste water input.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 3/34 - Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping with one or more auxiliary substances
C02F 1/10 - Treatment of water, waste water, or sewage by heating by distillation or evaporation by direct contact with a particulate solid or with a fluid, as a heat transfer medium
B01D 53/78 - Liquid phase processes with gas-liquid contact
B01D 1/18 - Evaporating by spraying to obtain dry solids
A gas turbine combined-cycle power plant can comprise a gas turbine engine, a heat recovery steam generator, a steam turbine, a fuel regasification system and a Rankine Cycle system. The gas turbine engine can comprise a compressor for generating compressed air, a combustor that can receive a fuel and the compressed air to produce combustion gas, and a turbine for receiving the combustion gas and generating exhaust gas. The heat recovery steam generator is configured to generate steam from water utilizing the exhaust gas. The steam turbine is configured to produce power from steam from the heat recovery steam generator. The fuel regasification system is configured to convert the fuel from a liquid to a gas before entering the combustor. The Organic Rankine Cycle system is configured to cool compressed air extracted from the compressor to cool the gas turbine engine, and heat liquid fuel entering the fuel regasification system.
F02C 6/04 - Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F02C 7/18 - Cooling of plants characterised by cooling medium the medium being gaseous, e.g. air
A combined-cycle power plant comprises a gas turbine engine for generating exhaust gas, an electric generator driven by the gas turbine engine, a steam generator receiving the exhaust gas to heat water and generate steam, and a duct burner system configured to heat exhaust gas in the steam generator before generating the steam and that comprises a source of hydrogen fuel, a fuel distribution manifold to distribute the hydrogen fuel in a duct of the steam generator, and an igniter to initiate combustion of the hydrogen fuel in the exhaust gas. A method for heating exhaust gas in a steam generator for a combined-cycle power plant comprises directing combustion gas of a gas turbine engine into a duct, introducing hydrogen fuel into the duct, combusting the hydrogen fuel and the combustion gas to generate heated gas, and heating water in the duct with the heated gas to generate steam.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01K 25/00 - Plants or engines characterised by use of special working fluids, not otherwise provided forPlants operating in closed cycles and not otherwise provided for
F23R 3/20 - Flame stabilising means, e.g. flame holders for after-burners of jet-propulsion plants incorporating fuel injection means
F23D 14/10 - Premix gas burners, i.e. in which gaseous fuel is mixed with combustion air upstream of the combustion zone induction type, e.g. Bunsen burner with elongated tubular burner head
F23D 14/22 - Non-premix gas burners, i.e. in which gaseous fuel is mixed with combustion air on arrival at the combustion zone with separate air and gas feed ducts, e.g. with ducts running parallel or crossing each other
F01K 23/06 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
Disclosed are systems and methods for active inlet turbine control. The systems and methods may include receiving a plurality of signals, determining a temperature gradient across an inlet of a gas turbine engine, and transmitting an activation signal to a modulating valve. Each of the plurality of signals may correspond to a temperature measured by one of a plurality of sensors located proximate the inlet of the gas turbine engine. The temperature gradient across the inlet of the gas turbine engine may be determined based on the plurality of signals. The activation signal may be operative to open or close the modulating valve based on the temperature gradient.
F02C 9/18 - Control of working fluid flow by bleeding, by-passing or acting on variable working fluid interconnections between turbines or compressors or their stages
Systems and methods for starting a gas turbine engine can comprise a generator to be driven by the gas turbine engine to supply power to a grid system, a first switch to electrically couple and decouple the generator from the grid system, a first static frequency converter having a first capacity, a second static frequency converter having a second capacity, control means for electrically coupling and decoupling the first and second static frequency converters from the grid system, a synchronizer and a controller configured to operate the generator as a starter-motor with power from: the first static frequency converter to turn the gas turbine engine at a first rate sufficient to start the gas turbine engine within a first time period or the first static frequency converter and the second static frequency converter in synchronization to turn the gas turbine engine at a second rate greater than the first rate.
A method for starting a steam turbine can comprise electrically decoupling a generator configured to be driven by the steam turbine from a power supply, controlling power from the power supply to a frequency converter, and operating the generator as a starter motor with power from the frequency converter to turn the steam turbine. A power plant system can comprise a steam turbine, a generator configured to be driven by the steam turbine to supply power to a grid system, a first switch to electrically couple and decouple the generator from the grid system, a frequency converter electrically coupled to the generator, and a second switch to electrically couple and decouple the frequency converter form the grid system.
A method of reducing applied heat within an inlet duct of a gas turbine generating electricity includes applying heat to the inlet duct of the gas turbine to attain an initial temperature set point and to produce conditions sufficient for preventing formation of ice within the inlet duct, measuring a position of an inlet guide vane (IGV) of the gas turbine, an inlet duct temperature, and an inlet duct relative humidity to determine a thermodynamic state in the inlet duct, evaluating the thermodynamic state to determine if the conditions are sufficient for preventing formation of ice within the inlet duct, and in response to determining that sufficient conditions exist within the inlet duct for preventing formation of ice, adjusting the applied heat to maintain the measured inlet duct temperature.
F02C 1/05 - Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly characterised by the type or source of heat, e.g. using nuclear or solar energy
A method for measuring a non-magnetic coating thickness upon a non-magnetic gas turbine component, such as a hot gas path component, can comprise applying a magnetic coating, such as a ferrous coating, upon the non-magnetic gas turbine component, applying a non-magnetic coating, such as a metallic bond coating, upon the magnetic coating, and measuring a thickness of the non-magnetic coating with a magnetic induction probe. The magnetic induction probe can be calibrated to the magnetic coating before the non-magnetic coating is applied. Measuring of the thickness of the non-magnetic coating can be used to validate spray patterns of automated spray processes. The magnetic and non-magnetic coatings can be stripped from the gas turbine component and used to validate additional spray patterns.
G01N 27/82 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables for investigating the presence of flaws
G01M 15/14 - Testing gas-turbine engines or jet-propulsion engines
39 - Transport, packaging, storage and travel services
40 - Treatment of materials; recycling, air and water treatment,
Goods & Services
(1) Storage of hydrogen gas, electricity, and clean energy, namely, natural gas, solar energy, wind energy, geothermal energy and biomass energy; distribution of hydrogen gas, electricity, and clean energy, namely, natural gas, solar energy, wind energy, geothermal energy and biomass energy to residential and commercial users; transportation of hydrogen gas by pipeline, rail and truck; transportation of electricity by cables and wires; transportation of clean energy, namely, natural gas, by pipelines.
(2) Generation of hydrogen gas, electricity, and clean energy, namely, natural gas, solar energy, wind energy, geothermal energy and biomass energy.
A gas turbine engine rotor assembly comprises a torque tube, turbine stage and stiffening mass. The torque tube comprises a shaft extending from a forward location to an aft end, and a shaft fastening flange disposed at the aft end. The turbine stage comprises a disc, a disc adapter extending forward from the disc, and a disc fastening flange extending from the disc adapter and couplable to the shaft fastening flange at an interface. The stiffening mass is positioned proximate the interface to reduce operational stress in the torque tube. A method of reducing operational stress in a rotor assembly comprises de-stacking a rotor stack, separating a first stage rotor disc adapter from a torque tube, attaching a stiffening mass to an inner diameter of one or both of the disc adapter and the torque tube, attaching the disc adapter to the torque tube, and re-stacking the rotor stack.
09 - Scientific and electric apparatus and instruments
11 - Environmental control apparatus
37 - Construction and mining; installation and repair services
42 - Scientific, technological and industrial services, research and design
Goods & Services
downloadable software for operation of large-scale renewable energy generation and storage facilities large-scale renewable energy generation and storage facilities, namely, power plants construction, maintenance, and repair of large-scale renewable energy generation and storage facilities providing temporary use of online non-downloadable software for operation of large-scale renewable energy generation and storage facilities; platform as a service (PAAS) services, namely, software platform for the operation of large-scale renewable energy generation and storage facilities; design of large-scale renewable energy generation and storage facilities
43.
Power plants using incongruent load imbalance response
A method (110) of controlling an imbalance response in a power plant comprising first and second gas turbine engines and a steam turbine driven by steam generated by exhaust from the first and second gas turbine engines can comprise operating the first gas turbine engine at a first power output (116A), operating the second gas turbine engine at a second power output (116B), monitoring load demand from a power grid operating at a steady state condition (114), detecting a load imbalance on the power grid (120) that causes a deviation from the steady state condition, and adjusting the first power output and the second power output incongruently (128) during the imbalance response to change the first power output and the second power output to match the deviation from the steady state condition depending on contemporaneous efficiency states of the first and second gas turbine engines.
H02J 3/46 - Controlling the sharing of output between the generators, converters, or transformers
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01K 13/02 - Controlling, e.g. stopping or starting
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.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
F01K 7/16 - Steam engine plants characterised by the use of specific types of enginePlants or engines characterised by their use of special steam systems, cycles or processesControl means specially adapted for such systems, cycles or processesUse of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
F01K 13/02 - Controlling, e.g. stopping or starting
F22B 1/18 - Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
An emissions reduction system for a combined cycle power plant having a gas turbine engine and a heat recovery steam generator (HRSG) can comprise a duct defining a flow space configured to receive exhaust gas from the gas turbine and convey the exhaust gas into the HRSG, and a louver system coupled to the duct that can comprise a plurality of emission medium panels extending across the flow space, the emission medium panels configured to be moved between a first position where adjacent filter medium panels extend contiguously across the flow space of the duct and a second position where adjacent filter medium panels include spaces therebetween to provide an unobstructed flow path and an actuator to move the plurality of panels between the first position and the second position.
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
F01N 13/00 - Exhaust or silencing apparatus characterised by constructional features
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01N 3/021 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for cooling, or for removing solid constituents of, exhaust by means of filters
F01N 13/08 - Other arrangements or adaptations of exhaust conduits
F01N 3/10 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust
F01N 3/20 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust characterised by methods of operationControl specially adapted for catalytic conversion
46.
Diversion systems for low emission start converter
An emission reduction system for a combined cycle power plant including a gas turbine and heat recovery steam generator (HRSG) can comprise a stationary emission converter in fluid communication with and disposed upstream of the HRSG, and a diversion system operably coupled to an exhaust passage of the gas turbine, the exhaust passage defining an exhaust path for exhaust gas of the gas turbine through the heat recovery steam generator, the diversion system operable to define a primary exhaust path excluding the stationary emission converter and a start-up exhaust path including the stationary emission converter.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
Disclosed are systems and methods for active inlet turbine control. The systems and methods may include receiving a plurality of signals, determining a temperature gradient across an inlet of a gas turbine engine, and transmitting an activation signal to a modulating valve. Each of the plurality of signals may correspond to a temperature measured by one of a plurality of sensors located proximate the inlet of the gas turbine engine. The temperature gradient across the inlet of the gas turbine engine may be determined based on the plurality of signals. The activation signal may be operative to open or close the modulating valve based on the temperature gradient.
F02C 9/18 - Control of working fluid flow by bleeding, by-passing or acting on variable working fluid interconnections between turbines or compressors or their stages
A hybrid power plant system including a gas turbine system and a coal fired boiler system inputs high oxygen content gas turbine flue gas into the coal fired boiler system, said gas turbine flue gas also including carbon dioxide that is desired to be captured rather than released to the atmosphere. Oxygen in the gas turbine flue gas is consumed in the coal fired boiler, resulting in relatively low oxygen content boiler flue gas stream to be processed. Carbon dioxide, originally included in the gas turbine flue gas, is subsequently captured by the post combustion capture apparatus of the coal fired boiler system, along with carbon diode generated by the burning of coal. The supply of gas turbine flue gas which is input into the boiler system is controlled using dampers and/or fans by a controller based on an oxygen sensor measurement and one or more flow rate measurements.
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F22B 1/18 - Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
F01K 7/16 - Steam engine plants characterised by the use of specific types of enginePlants or engines characterised by their use of special steam systems, cycles or processesControl means specially adapted for such systems, cycles or processesUse of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
F02C 3/04 - Gas-turbine plants characterised by the use of combustion products as the working fluid having a turbine driving a compressor
F02C 9/50 - Control of fuel supply conjointly with another control of the plant with control of working fluid flow
F01D 19/02 - Starting of machines or enginesRegulating, controlling, or safety means in connection therewith dependent on temperature of component parts, e.g. of turbine casing
F23J 15/00 - Arrangements of devices for treating smoke or fumes
B01D 53/94 - Chemical or biological purification of waste gases of engine exhaust gases by catalytic processes
F01D 15/10 - Adaptations for driving, or combinations with, electric generators
H02K 7/18 - Structural association of electric generators with mechanical driving motors, e.g.with turbines
According to one example, an assembly for a repair of a compressor casing of a gas turbine engine is disclosed. The assembly can comprise: an arcuate track configured to be mounted to the casing, wherein when mounted to the casing the track is configured to be spaced in a substantially concentric arrangement from an inner surface of the casing; a carrier coupled to the track and movable therealong; and a machining device mounted to the carrier, the carrier configured to adjust at least an axial position of the machining device relative to the track for machining the inner surface of the casing.
Devices, systems and methods of the present disclosure can include a guide for installing an airfoil component in a slotted component of a gas turbine engine. The guide can comprise a guide body, a guide slot and an alignment appendage. The guide body can comprise a slot-facing side, an entry side, and a radially outer side surface connecting the slot-facing side and the entry side. The guide slot can extend from the entry side to the slot-facing side and can penetrate the radially outer side surface. The guide slot can have a silhouette matching that of a root portion of the airfoil component. The alignment appendage can extend from the guide body and can have a geometry for axial engagement with a circumferential feature of the slotted component into which the airfoil component is to be installed.
B23P 19/04 - Machines for simply fitting together or separating metal parts or objects, or metal and non-metal parts, whether or not involving some deformationTools or devices therefor so far as not provided for in other classes for assembling or disassembling parts
A hybrid power plant system including a gas turbine system and a coal fired boiler system inputs high oxygen content gas turbine flue gas into the coal fired boiler system, said gas turbine flue gas also including carbon dioxide that is desired to be captured rather than released to the atmosphere. Oxygen in the gas turbine flue gas is consumed in the coal fired boiler, resulting in relatively low oxygen content boiler flue gas stream to be processed. Carbon dioxide, originally included in the gas turbine flue gas, is subsequently captured by the post combustion capture apparatus of the coal fired boiler system, along with carbon diode generated by the burning of coal. The supply of gas turbine flue gas which is input into the boiler system is controlled using dampers and/or fans by a controller based on an oxygen sensor measurement and one or more flow rate measurements.
F01K 7/16 - Steam engine plants characterised by the use of specific types of enginePlants or engines characterised by their use of special steam systems, cycles or processesControl means specially adapted for such systems, cycles or processesUse of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
F02C 3/04 - Gas-turbine plants characterised by the use of combustion products as the working fluid having a turbine driving a compressor
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
B01D 53/94 - Chemical or biological purification of waste gases of engine exhaust gases by catalytic processes
F01D 15/10 - Adaptations for driving, or combinations with, electric generators
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F02C 9/50 - Control of fuel supply conjointly with another control of the plant with control of working fluid flow
H02K 7/18 - Structural association of electric generators with mechanical driving motors, e.g.with turbines
F01D 19/02 - Starting of machines or enginesRegulating, controlling, or safety means in connection therewith dependent on temperature of component parts, e.g. of turbine casing
F23J 15/00 - Arrangements of devices for treating smoke or fumes
F22B 1/18 - Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
A waste water processing system includes an upflow contacting column having a flue gas input for receiving flue gas having a temperature of at least 500 degrees F., a waste water input, and a flue gas output. The waste water input is coupled to a fluid injector, e.g., atomizing nozzles, positioned in the throat of a Venturi portion of the upflow contacting column or in a sidewall of the throat of the Venturi portion of the upflow contacting column. The flue gas in the upflow contacting column has a high velocity, e.g., a gas velocity exceeding 65 fps in the throat of the Venturi portion of the upflow contacting column at a position where the fluid injector is located. Drying additives such as recycled ash, lime, and/or cement may be, and sometimes are, input into the upflow contacting column downstream of the waste water input.
B01D 3/34 - Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping with one or more auxiliary substances
C02F 1/10 - Treatment of water, waste water, or sewage by heating by distillation or evaporation by direct contact with a particulate solid or with a fluid, as a heat transfer medium
A static mixer is described in which rows of mixing plates are used in a combination with nozzles that are located with respect to the mixing plates in a manner that is designed to produce a high level of mixing without significantly impeding the flow of flue gas passing through the rows of mixer plates. In various embodiments, the static mixer includes rows of tilted plates, and the injection lance nozzles are positioned to align with row boundaries corresponding to the boundaries between consecutive rows of mixing plates. In some embodiments, there are N rows of mixing plates and N-1 rows of nozzles. In some embodiments the nozzles are positioned to coincide with the boundaries between rows. The mixer assembly including injection nozzles and/or lances can be implemented in a relatively compact manner allowing for it to be placed in a shorter length of flue than many other mixer assemblies.
Methods and systems for controlling the temperature of a heated flue gas stream downstream of a multi-part heat exchanger within a desired operating range through the use of a fluid bypass line which bypasses one or more sections, but not all sections, of the multi-part heat exchanger. In some but not necessarily all embodiments some fluid flow is maintained through the heat exchanger at all times. In one embodiment, the method includes sensing a temperature in said flue gas stream in proximity to an intermediate header of said multi-part heat exchanger and controlling a position of a bypass line control valve to control an amount of fluid passing through a fluid bypass line that bypasses the section of the multi-part heat exchanger between an inlet header and the intermediate header based on said temperature in said flue gas stream in proximity to the intermediate header of said multi-part heat exchanger.
Methods and systems for controlling the temperature of a heated flue gas stream downstream of a multi-part heat exchanger within a desired operating range through the use of a fluid bypass line which bypasses one or more sections, but not all sections, of the multi-part heat exchanger. In some but not necessarily all embodiments some fluid flow is maintained through the heat exchanger at all times. In one embodiment, the method includes sensing a temperature in said flue gas stream in proximity to an intermediate header of said multi-part heat exchanger and controlling a position of a bypass line control valve to control an amount of fluid passing through a fluid bypass line that bypasses the section of the multi-part heat exchanger between an inlet header and the intermediate header based on said temperature in said flue gas stream in proximity to the intermediate header of said multi-part heat exchanger.
Methods and apparatus for pollution control which are well suited for use in a coal power plant are described. Ash is collected and injected into the flue gas stream at a location upstream of a cooling module. The ash acts as an absorbent and/or reactant material onto which condensate may condense. By re-introducing ash to keep the condensation forming wet areas within the system, lower cost materials which are less corrosion resistant than needed for wet operating conditions can be used. Mercury recovery and SO3 removal is facilitated by the cooling process and re-introduction of collected ash. Activated carbon and/or an alkali absorbent material may be added. Use of a dry ESP and/or fabric filter as opposed to a wet ESP for particulate collection leads to cost benefits. Energy recovered by the cooling of the flue gas may be re-used to heat turbine condensate leading to improved energy efficiency.
B01D 53/06 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography with moving adsorbents
An apparatus for a gas turbine power plant that uniquely configures emission control equipment such that the plant can extend the emissions compliant operational range, the apparatus including a plurality of oxidation (CO) catalysts arranged in series, optimized SCR for high NO2 reduction, Control valves with added capabilities for low turndown and other characteristics.
F01K 23/10 - Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
F01N 3/10 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
F23R 3/40 - Continuous combustion chambers using liquid or gaseous fuel characterised by the use of catalytic means
