Abstract: A fuel injector for a gas turbine combustor includes a fuel conduit fitting and a nozzle having an inlet portion defining a mixing chamber therein. The inlet portion includes a plurality of circumferentially-spaced vanes that define a plurality of inlet flow paths within the mixing chamber. Each vane has at least one port defined therein that is in flow communication with the fuel conduit fitting such that fuel from the fuel conduit fitting is dischargeable into at least one of the inlet flow paths via the at least one port. The resulting fuel/air mixture is delivered into a secondary combustion zone of the gas turbine combustor. A gas turbine including the fuel injector and a method of fabricating the fuel nozzle are also provided.

Abstract: A control system for a gas turbine engine, a method for controlling a gas turbine engine, and a gas turbine engine are disclosed. The control system may include a nozzle scheduler for determining an exhaust nozzle position goal based on a nozzle schedule of exhaust nozzle positions related to flight conditions. The control system may further include a control module for determining a control command for the gas turbine engine. The control command may include, at least, a fuel flow command and an exhaust nozzle position command and the control command may be based on, at least, the exhaust nozzle position goal and an estimated thrust value. The control system may further include an actuator for controlling the gas turbine engine based on the control command.

Abstract: A system and related method for providing a highly reactive fuel to a combustor of a gas turbine are disclosed herein. The system includes a fuel supply system that is in fluid communication with a fuel supply. The fuel supply system includes multiple fuel circuits. Each fuel circuit individually feeds fuel to a corresponding fuel distribution manifold. The system further includes a steam injection system. The steam injection system includes at least one flow control valve that is in fluid communication with at least one of the fuel circuits. The flow control valve provides for fluid communication between a superheated steam source and the fuel circuit during both fueled operation and during non-fueled operation of the corresponding fuel circuit.

Abstract: A closed cycle plant for converting thermal power to mechanical or electrical power including: a closed circuit inside which a working fluid circulates according to a predetermined circulation direction, a volumetric expander configured to receive at the inlet the working fluid in a gaseous state. The volumetric expander includes: a jacket having an inlet and an outlet for enabling the introduction and discharge the working fluid; an active element housed in said jacket and suitable for defining, in cooperation with said jacket, a variable volume expansion chamber; a main shaft; a valve active that opens and closes the inlet and outlet, and a generator connected to the main shaft. The valve includes a regulation device configured to vary the duration of the introduction condition, or the maximum through cross-section of the inlet.

Abstract: Variable speed drive controlled discharge pumps are used for pumping chilled water from a chilled water storage tank to coils operatively associated with the air inlet of a gas turbine, wherein the gas turbine is used to generate electricity. Use of the variable speed drive controlled discharge pumps aids is protecting the temperature distribution in the chilled water storage tank so that a thermocline rises with the addition of chilled water during charging of the tank with chilled water, and lowers during discharge of the tank when using the chilled water to cool inlet air at one or more gas turbines operated at a facility.

Abstract: A reformer for use in a gas turbine engine specially configured to treat a supplemental fuel feed to the combustor that includes a reformer core containing a catalyst composition and an inlet flow channel for transporting the reformer fuel mixture, air and steam (either saturated or superheated) into a reformer core. An outlet flow channel transports the resulting reformate stream containing reformed and thermally cracked hydrocarbons and substantial amounts of hydrogen out of the reformer core for later combination with the main combustor feed. Because the catalytic partial oxidation reaction in the reformer is highly exothermic, the additional heat is transferred (and thermally integrated) using one or more heat exchange units for a first and/or second auxiliary gas turbine fuel stream that undergo thermal cracking and vaporization before combining with the reformate. The combined, hydrogen-enriched feed significantly improves combustor performance.

Abstract: A combustion burner 10A according to one embodiment of the present invention includes: a fuel nozzle 110; a burner tube 120 forming the air passage 111 between the burner tube 120 and the fuel nozzle 110; swirler vanes (swirler vanes) 130 arranged in a plurality of positions in the circumferential direction on the external circumferential surface of the fuel nozzle 110, each extending along the axial direction of the fuel nozzle 110, and gradually curving from upstream toward downstream; and a liquid fuel injecting hole 133A from which a liquid fuel is injected to a surface of each of the swirler vanes 130. The combustion burner 10A also includes multi-purpose injecting holes 11-1 to 11-3 as a cooling unit that cools a part of a vane pressure surface 132a of the swirler vane 130 on which the liquid fuel LF hits.

Abstract: A combined cycle power generation system (10) includes a steam turbine (14, 16, 18), a combustion system (12) including a compressor (24), a combustion chamber (26), a gas turbine (28), and a HRSG (20) to generate steam with energy from the combustion turbine. A flow line (60, 70) passes superheated steam into the combustion chamber. In an associated method a first source of power is provided via a combustion process having a variable reaction temperature in a first turbine. A second source of power is provided via a second turbine. Components of the system are placed in a mode of increasing power output with steam generated from the HRSG, during which a portion of the steam is provided into a combustion chamber associated with operation of the second turbine.

Abstract: A turbine engine includes an air inlet fluidly coupleable with an air compressor subassembly. The air compressor subassembly is fluidly coupleable with a combustion subassembly. The combustion subassembly generates and combusts ionic hydrogen, and is fluidly coupleable with a mid-turbine subassembly. The mid-turbine subassembly is fluidly coupleable with a rear turbine subassembly. The rear turbine subassembly is fluidly coupleable with an exhaust outlet for exhausting combustion products from said mid-turbine subassembly. The combustion subassembly includes an electrostatic subassembly fluidly coupleable with a combustion chamber subassembly. The combustion chamber subassembly is fluidly coupleable with the mid-turbine subassembly. The air compressor subassembly can compress and humidify air.

Abstract: Methods and systems are provided for inducing combustion dynamics within turbine engines to remove combustion deposits within the turbine engine during operation of the turbine engine.

Abstract: A mixture of air and fuel is received into a reaction chamber of a gas turbine system. The fuel is oxidized in the reaction chamber, and a maximum temperature of the mixture in the reaction chamber is controlled to be substantially at or below an inlet temperature of a turbine of the gas turbine system. The oxidation of the fuel is initiated by raising the temperature of the mixture to or above an auto-ignition temperature of the fuel. In some cases, the reaction chamber may be provided without a fuel oxidation catalyst material.

Abstract: A combustion burner 10A according to one embodiment of the present invention includes: a fuel nozzle 110; a burner tube 120 forming the air passage 111 between the burner tube 120 and the fuel nozzle 110; swirler vanes (swirler vanes) 130 arranged in a plurality of positions in the circumferential direction on the external circumferential surface of the fuel nozzle 110, each extending along the axial direction of the fuel nozzle 110, and gradually curving from upstream toward downstream; and a liquid fuel injecting hole 133A from which a liquid fuel is injected to a surface of each of the swirler vanes 130. The combustion burner 10A also includes multi-purpose injecting holes 11-1 to 11-3 as a cooling unit that cools a part of a vane pressure surface 132a of the swirler vane 130 on which the liquid fuel LF hits.

Abstract: A method of controlling a combustor of a gas turbine is disclosed. The method includes operatively disposing a combustor can in a combustor of a gas turbine. The combustor can comprising a plurality of combustor fuel nozzles, each having a fuel injector and configured to selectively provide a liquid fuel, a liquid fluid or liquid fuel and liquid fluid to a fuel injector nozzle that is configured to provide, respectively, a plurality of liquid fuel jets, a plurality of liquid fluid jets or a combination thereof, that are in turn configured to provide an atomized liquid fuel stream, an atomized liquid fluid stream, or an atomized and emulsified liquid fuel-liquid fluid stream, respectively. The method also includes selectively providing an amount of fuel, fluid or a combination thereof to the fuel injector nozzle to produce an atomized fuel stream, atomized fluid stream, or an atomized and emulsified fuel-fluid stream, respectively.

Abstract: Clean combustion and equilibration equipment and methods are provided to progressively deliver, combust and equilibrate mixtures of fuel, oxidant and aqueous diluent in a plurality of combustion regions and in one or more equilibration regions to further progress oxidation of products of incomplete combustion, in a manner that sustains combustion while controlling temperatures and residence times sufficiently to reduce CO and NOx emissions to below 25 ppmvd, and preferably to below 3 ppmvd at 15% O2.

Abstract: Provided are more efficient techniques for operating gas turbine systems. In one embodiment a gas turbine system comprises an oxidant system, a fuel system, a control system, and a number of combustors adapted to receive and combust an oxidant from the oxidant system and a fuel from the fuel system to produce an exhaust gas. The gas turbine system also includes a number of oxidant-flow adjustment devices, each of which are operatively associated with one of the combustors, wherein an oxidant-flow adjustment device is configured to independently regulate an oxidant flow rate into the associated combustor. An exhaust sensor is in communication with the control system. The exhaust sensor is adapted to measure at least one parameter of the exhaust gas, and the control system is configured to independently adjust each of the oxidant-flow adjustment devices based, at least in part, on the parameter measured by the exhaust sensor.

Abstract: A steam generation system comprises: an oxygenated water treatment (OWT) sub-system configured to generate water having oxidizing chemistry; a steam generation sub-system configured to convert the water having oxidizing chemistry into steam having oxidizing chemistry; an attemperator or other injection device or devices configured to add an oxygen scavenger to the steam having oxidizing chemistry to generate steam having less oxidizing or reducing chemistry; and a condenser configured to condense the steam having less oxidizing or reducing chemistry into condensed water.

Abstract: An internal-combustion engine receives no air from outside atmosphere and it discharges no gas into outside atmosphere. The engine receives fuel, oxygen and recycled combustion gas and its exhaust consists mostly of carbon dioxide and water vapor. Most of the gas exhausted from the engine is recycled back into the engine intake, and the remaining gas is cooled and condensed into liquid carbon dioxide and water. Discharge of greenhouse gas into environment and emission of other harmful air pollutants are eliminated.

Abstract: A thermodynamic system that produces mechanical, electrical power, and/or fluid streams for heating or cooling. The cycle contains a combustion system that produces an energetic fluid by combustion of a fuel with an oxidant. A thermal diluent may be used in the cycle to improve performance, including but not limited to power, efficiency, economics, emissions, dynamic and off-peak load performance, and/or turbine inlet temperature (TIT) regulation and cooling heated components. The cycle preferably includes a heat recovery system and a condenser or other means to recover and recycle heat and the thermal diluent from the energetic fluid to improve the cycle thermodynamic efficiency and reduce energy conversion costs. The cycle may also include controls for temperatures, pressures, and flow rates throughout the cycle, and controls power output, efficiency, and energetic fluid composition.

Abstract: System, methods and apparatus for dynamic control of mixing of diluent and fuel at desired diluent-to-fuel ratios to obtain low level of undesirable emissions in a combustion system are described.

Abstract: A method and system for modulating the Modified Wobbe Index (MWI) of a fuel is provided. A variety of industrial components, which may require a gas fuel, such as but not limiting of, a heavy-duty gas turbine; an aero-derivative gas turbine; or a boiler may utilize the method and system. The method and system may provide an industrial component comprising at least one steam injection system, wherein the at least one steam injection system injects steam into at least one fuel supply line upstream of a combustion system to modulate the MWI of at least one fuel. The method and system may also determine whether the MWI of the at least one fuel is outside of a predetermined range; and utilize the at least one steam injection system to automatically inject the steam at a flowrate for adjusting the MWI of the at least one fuel.

Abstract: In a method for operating a gas turbine plant (10) with a compressor (11) for the compression of combustion air sucked in from the surroundings, with a combustion chamber (15) for generating hot gas by the combustion of a fuel with compressed combustion air, and with a turbine (12), in which the hot gas from the combustion chamber (15) is expanded so as to perform work, temperatures and pressures are measured at various points in the gas turbine plant (10), and a combustion chamber exit temperature is derived from the measured temperatures and pressures and used for controlling the gas turbine plant (10). Improved temperature determination is achieved in that the composition of the gas, in particular the water content in the exhaust gas of the turbine (12), is determined, and in that the specific water content in the exhaust gas of the turbine (12) is taken into account in deriving the combustion chamber exit temperature.

Abstract: Methods and systems are provided for inducing combustion dynamics within turbine engines to remove combustion deposits within the turbine engine during operation of the turbine engine.

Abstract: A method and system for modulating the Modified Wobbe Index (MWI) of a fuel is provided. A variety of industrial components, which may require a gas fuel, such as but not limiting of, a heavy-duty gas turbine; an aero-derivative gas turbine; or a boiler may utilize the method and system. The method and system may provide an industrial component comprising at least one steam injection system, wherein the at least one steam injection system injects steam into at least one fuel supply line upstream of a combustion system to modulate the MWI of at least one fuel. The method and system may also determine whether the MWI of the at least one fuel is outside of a predetermined range; and utilize the at least one steam injection system to automatically inject the steam at a flowrate for adjusting the MWI of the at least one fuel.

Abstract: A remediation system and method for decontaminating a polluted site. An outlet system is to deliver a remediation fluid to the polluted site, and an inlet system receives a contaminated effluent from the polluted site. A processing system extracts a contaminant component from the contaminated effluent. A reactor receives the extracted contaminant component as a first reactant, and also, a second reactant. The reactor generates a reaction product-containing exit fluid stream, a controlled portion of which is released from the system. The remaining portion of the reactor exit fluid forms the remediation fluid. Optionally, the remaining portion is combined with a controlled quantity of the second reactant to form the remediation fluid. In addition, a controlled quantity of diluent/coolant fluid may be delivered into a reaction process in the reactor and/or downstream of the reaction process, and/or separately in a heat transfer system.

Abstract: A gas turbine group is provided with at least one cooling apparatus for cooling the working medium before and/or during the compression. The cooling power of the cooling apparatus can be adjusted by suitable means. A controller controls the cooling power of the cooling apparatus as a function of a control deviation in the useful power of the gas turbine group. The cooling controller interacts with other controllers of the gas turbine group in such a way that the gas turbine group is itself always operated at least close to its full load operating state. In this context, it is preferable for the inlet guide vane row of the compressor to be maximally open, and for the hot-gas temperature on entry into the turbines to be controlled so that it is constantly at an upper limit value.

Abstract: A power generating system and method operating at high pressure and utilizing a working fluid consisting of a mixture of compressed non-flammable air components, fuel combustion products and steam. The working fluid is substantially free of CO and NOx. Fuel and compressed air at an elevated temperature and at a constant pressure are delivered to a combustion chamber, the amount of air being chosen so that at least about 90% of the oxygen in the air is consumed during combustion. The quantity of air and fuel supplied to the combustion chamber may be varied provided a constant fuel to air ratio is maintained. Superheated water is delivered under pressure to the combustion chamber, and is converted substantially instantaneously to steam. The quantity of water delivered is controlled such that the latent heat of vaporization of the water maintains the temperature of the working fluid at a desired level.

Abstract: A power generating system and method operating at high pressure and utilizing a working fluid consisting of a mixture of compressed non-flammable air components, fuel combustion products and steam. The working fluid is substantially free of CO and NOx. Fuel and compressed air at an elevated temperature and at a constant pressure are delivered to a combustion chamber, the amount of air being chosen so that at least about 90% of the oxygen in the air is consumed during combustion. The quantity of air and fuel supplied to the combustion chamber may be varied provided a constant fuel to air ratio is maintained. Superheated water is delivered under pressure to the combustion chamber, and is converted substantially instantaneously to steam. The quantity of water delivered is controlled such that the latent heat of vaporization of the water maintains the temperature of the working fluid at a desired level.

Abstract: A method and apparatus for reducing emissions in combustion systems, particularly gas turbines. A mixture of diluent and fuel is created, wherein the diluent and the fuel are at a predetermined diluent-to-fuel ratio. The mixture is homogenized to create a homogenized mixture having a uniform concentration distribution of the diluent and the fuel at the predetermined diluent-fuel ratio. Thereafter, the homogenized mixture is introduced into a flame zone and the homogenized mixture is combusted.

Abstract: A gas turbine steam cooled system has a high temperature portion 8 outlet steam temperature maintained to a predetermined value without a cooling steam pressure becoming lower than the pressure in the gas turbine cylinder. Steam coming from an intermediate pressure superheater 10 of a waste heat recovery boiler 2 is led into the high temperature portion 8 of the gas turbine for cooling thereof. The temperature of the cooling steam at the outlet of the high temperature portion 8 is detected by a high temperature portion outlet steam temperature detector 15, and a signal thereof is sent a lower value selector 19 via a temperature controller 11. Pressure in the gas turbine cylinder is detected by a gas turbine cylinder pressure detector 17, and pressure of the cooling steam at the high temperature portion 8 outlet is detected by a high temperature portion outlet steam pressure detector 16. A differential signal thereof is sent to a pressure controller 18.

Abstract: A power generating system is described which operates at high pressure and utilizes a working fluid consisting of a mixture of compressed non-flammable air components, fuel combustion products and steam. The working fluid exiting the power generating system is substantially free of NOx and CO. Working fluid is provided at constant pressure and temperature. Combustion air is supplied by one or more stages of compression. Fuel is injected at pressure as needed. At least about 40% of the oxygen in the compressed air is consumed when the fuel is burned. Inert liquid is injected at high pressure to produce working an inert mass of high specific heat diluent vapor for use for internal cooling of the combustion chamber. The use of non-flammable liquid injection inhibits the formation of pollutants, increases the efficiency and available horsepower from the system, and reduces specific fuel consumption.

Abstract: An internally cooled internal combustion piston engine and method of operating a piston engine is provided, with the combination of liquid water injection, higher compression ratios than conventional engines, and leaner air fuel mixtures than conventional engines. The effective compression ratio of the engines herein is greater than 13:1. The engines may employ gasoline or natural gas and use spark ignition, or the engines may employ a diesel-type fuel and use compression ignition. The liquid water injection provides internal cooling, reducing or eliminating the heat rejection to the radiator, reduces engine knock, and reduces NOx emissions. The method of engine operation using internal cooling with liquid water injection, high compression ratio and lean air fuel mixture allow for more complete and efficient combustion and therefore better thermal efficiency as compared to conventional engines.